ENTERGY ARKANSAS, LLC - Annual Report: 2011 (Form 10-K)

a10-k.htm

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

(Mark One)

X	ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

	For the Fiscal Year Ended December 31, 2011
	OR
	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

	For the transition period from ____________ to ____________

Commission File Number	Registrant, State of Incorporation or Organization, Address of Principal Executive Offices, Telephone Number, and IRS Employer Identification No.	Commission File Number	Registrant, State of Incorporation or Organization, Address of Principal Executive Offices, Telephone Number, and IRS Employer Identification No.
1-11299	ENTERGY CORPORATION (a Delaware corporation) 639 Loyola Avenue New Orleans, Louisiana 70113 Telephone (504) 576-4000 72-1229752	1-31508	ENTERGY MISSISSIPPI, INC. (a Mississippi corporation) 308 East Pearl Street Jackson, Mississippi 39201 Telephone (601) 368-5000 64-0205830


1-10764	ENTERGY ARKANSAS, INC. (an Arkansas corporation) 425 West Capitol Avenue Little Rock, Arkansas 72201 Telephone (501) 377-4000 71-0005900	0-05807	ENTERGY NEW ORLEANS, INC. (a Louisiana corporation) 1600 Perdido Street New Orleans, Louisiana 70112 Telephone (504) 670-3700 72-0273040


0-20371	ENTERGY GULF STATES LOUISIANA, L.L.C. (a Louisiana limited liability company) 446 North Boulevard Baton Rouge, Louisiana 70802 Telephone (800) 368-3749 74-0662730	1-34360	ENTERGY TEXAS, INC. (a Texas corporation) 350 Pine Street Beaumont, Texas 77701 Telephone (409) 981-2000 61-1435798


1-32718	ENTERGY LOUISIANA, LLC (a Texas limited liability company) 446 North Boulevard Baton Rouge, Louisiana 70802 Telephone (800) 368-3749 75-3206126	1-09067	SYSTEM ENERGY RESOURCES, INC. (an Arkansas corporation) Echelon One 1340 Echelon Parkway Jackson, Mississippi 39213 Telephone (601) 368-5000 72-0752777

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Securities registered pursuant to Section 12(b) of the Act:

Registrant	Title of Class	Name of Each Exchange on Which Registered

Entergy Corporation	Common Stock, $0.01 Par Value – 176,620,417 shares outstanding at January 31, 2012	New York Stock Exchange, Inc. Chicago Stock Exchange, Inc.

Entergy Arkansas, Inc.	Mortgage Bonds, 5.75% Series due November 2040	New York Stock Exchange, Inc.

Entergy Louisiana, LLC	Mortgage Bonds, 6.0% Series due March 2040	New York Stock Exchange, Inc.
	Mortgage Bonds, 5.875% Series due June 2041	New York Stock Exchange, Inc.

Entergy Mississippi, Inc.	Mortgage Bonds, 6.0% Series due November 2032	New York Stock Exchange, Inc.
	Mortgage Bonds, 6.20% Series due April 2040	New York Stock Exchange, Inc.
	Mortgage Bonds, 6.0% Series due May 2051	New York Stock Exchange, Inc.

Entergy Texas, Inc.	Mortgage Bonds, 7.875% Series due June 2039	New York Stock Exchange, Inc.

Securities registered pursuant to Section 12(g) of the Act:

Registrant	Title of Class

Entergy Arkansas, Inc.	Preferred Stock, Cumulative, $100 Par Value Preferred Stock, Cumulative, $0.01 Par Value

Entergy Gulf States Louisiana, L.L.C.	Common Membership Interests

Entergy Mississippi, Inc.	Preferred Stock, Cumulative, $100 Par Value

Entergy New Orleans, Inc.	Preferred Stock, Cumulative, $100 Par Value

Entergy Texas, Inc.	Common Stock, no par value

Indicate by check mark if the registrants are well-known seasoned issuers, as defined in Rule 405 of the Securities Act.

	Yes	No

Entergy Corporation	Ö
Entergy Arkansas, Inc.		Ö
Entergy Gulf States Louisiana, L.L.C.		Ö
Entergy Louisiana, LLC	Ö
Entergy Mississippi, Inc.		Ö
Entergy New Orleans, Inc.		Ö
Entergy Texas, Inc.		Ö
System Energy Resources, Inc.		Ö

Indicate by check mark if the registrants are not required to file reports pursuant to Section 13 or Section 15(d) of the Act.

	Yes	No

Entergy Corporation		Ö
Entergy Arkansas, Inc.		Ö
Entergy Gulf States Louisiana, L.L.C.		Ö
Entergy Louisiana, LLC		Ö
Entergy Mississippi, Inc.		Ö
Entergy New Orleans, Inc.		Ö
Entergy Texas, Inc.		Ö
System Energy Resources, Inc.		Ö

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Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days. Yes þ No o

Indicate by check mark whether the registrants have submitted electronically and posted on Entergy’s corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No o

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of the registrants’ knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. [ ]

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See definitions of “accelerated filer,” “large accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Securities Exchange Act of 1934.

	Large accelerated filer	Accelerated filer	Non-accelerated filer	Smaller reporting company

Entergy Corporation	Ö
Entergy Arkansas, Inc.			Ö
Entergy Gulf States Louisiana, L.L.C.			Ö
Entergy Louisiana, LLC			Ö
Entergy Mississippi, Inc.			Ö
Entergy New Orleans, Inc.			Ö
Entergy Texas, Inc.			Ö
System Energy Resources, Inc.			Ö

Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Act.) Yes o No þ

System Energy Resources meets the requirements set forth in General Instruction I(1) of Form 10-K and is therefore filing this Form 10-K with reduced disclosure as allowed in General Instruction I(2). System Energy Resources is reducing its disclosure by not including Part III, Items 10 through 13 in its Form 10-K.

The aggregate market value of Entergy Corporation Common Stock, $0.01 Par Value, held by non-affiliates as of the end of the second quarter of 2011, was $12.1 billion based on the reported last sale price of $68.28 per share for such stock on the New York Stock Exchange on June 30, 2011. Entergy Corporation is the sole holder of the common stock of Entergy Arkansas, Inc., Entergy Mississippi, Inc., Entergy New Orleans, Inc., Entergy Texas, Inc., and System Energy Resources, Inc. Entergy Corporation is the sole holder of the common stock of Entergy Louisiana Holdings, Inc., which is the sole holder of the common membership interests in Entergy Louisiana, LLC. Entergy Corporation is the sole holder of the common stock of EGS Holdings, Inc., which is the sole holder of the common membership interests in Entergy Gulf States Louisiana, L.L.C.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the Proxy Statement of Entergy Corporation to be filed in connection with its Annual Meeting of Stockholders, to be held May 4, 2012, are incorporated by reference into Part III hereof.

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TABLE OF CONTENTS

	SEC Form 10-K Reference Number	Page Number

Forward-looking information		iv
Definitions		vii
Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis	Part II. Item 7.	1
Selected Financial Data - Five-Year Comparison	Part II. Item 6.	44
Report of Independent Registered Public Accounting Firm		45
Consolidated Income Statements For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	46
Consolidated Statements of Comprehensive Income For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	47
Consolidated Statements of Cash Flows For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	48
Consolidated Balance Sheets, December 31, 2011 and 2010	Part II. Item 8.	50
Consolidated Statements of Changes in Equity for the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	52
Notes to Financial Statements	Part II. Item 8.	53
Entergy’s Business	Part I. Item 1.
Utility	Part I. Item 1.	195
Entergy Wholesale Commodities	Part I. Item 1.	214
Entergy-Koch	Part I. Item 1.	218
Regulation of Entergy’s Business	Part I. Item 1.	218
Litigation		234
Employees		236
Availability of SEC filings and other information on Entergy’s website		237
Risk Factors	Part I. Item 1A.	238
Unresolved Staff Comments	Part I. Item 1B.	None
Entergy Arkansas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis	Part II. Item 7.	259
Report of Independent Registered Public Accounting Firm		273
Consolidated Income Statements For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	274
Consolidated Statements of Cash Flows For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	275
Consolidated Balance Sheets, December 31, 2011 and 2010	Part II. Item 8.	276
Consolidated Statements of Changes in Common Equity for the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	278
Selected Financial Data - Five-Year Comparison	Part II. Item 6.	279
Entergy Gulf States Louisiana, L.L.C.
Management’s Financial Discussion and Analysis	Part II. Item 7.	280
Report of Independent Registered Public Accounting Firm		294
Income Statements For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	295
Statements of Comprehensive Income For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	296
Statements of Cash Flows For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	297
Balance Sheets, December 31, 2011 and 2010	Part II. Item 8.	298

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Statements of Changes in Equity for the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	300
Selected Financial Data - Five-Year Comparison	Part II. Item 6.	301
Entergy Louisiana, LLC and Subsidiaries
Management’s Financial Discussion and Analysis	Part II. Item 7.	302
Report of Independent Registered Public Accounting Firm		318
Consolidated Income Statements For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	319
Consolidated Statements of Comprehensive Income For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	320
Consolidated Statements of Cash Flows For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	321
Consolidated Balance Sheets, December 31, 2011 and 2010	Part II. Item 8.	322
Consolidated Statements of Change in Equity for the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	324
Selected Financial Data - Five-Year Comparison	Part II. Item 6.	325
Entergy Mississippi, Inc.
Management’s Financial Discussion and Analysis	Part II. Item 7.	326
Report of Independent Registered Public Accounting Firm		337
Income Statements For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	338
Statements of Cash Flows For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	339
Balance Sheets, December 31, 2011 and 2010	Part II. Item 8.	340
Statements of Changes in Common Equity for the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	342
Selected Financial Data - Five-Year Comparison	Part II. Item 6.	343
Entergy New Orleans, Inc.
Management’s Financial Discussion and Analysis	Part II. Item 7.	344
Report of Independent Registered Public Accounting Firm		355
Income Statements For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	356
Statements of Cash Flows For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	357
Balance Sheets, December 31, 2011 and 2010	Part II. Item 8.	358
Statements of Changes in Common Equity for the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	360
Selected Financial Data - Five-Year Comparison	Part II. Item 6.	361
Entergy Texas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis	Part II. Item 7.	362
Report of Independent Registered Public Accounting Firm		373
Consolidated Income Statements For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	374
Consolidated Statements of Cash Flows For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	375
Consolidated Balance Sheets, December 31, 2011 and 2010	Part II. Item 8.	376
Consolidated Statements of Changes in Common Equity for the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	378
Selected Financial Data - Five-Year Comparison	Part II. Item 6.	379
System Energy Resources, Inc.
Management’s Financial Discussion and Analysis	Part II. Item 7.	380
Report of Independent Registered Public Accounting Firm		387

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Income Statements For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	388
Statements of Cash Flows For the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	389
Balance Sheets, December 31, 2011 and 2010	Part II. Item 8.	390
Statements of Changes in Common Equity for the Years Ended December 31, 2011, 2010, and 2009	Part II. Item 8.	392
Selected Financial Data - Five-Year Comparison	Part II. Item 6.	393
Properties	Part I. Item 2.	394
Legal Proceedings	Part I. Item 3.	394
Mine Safety Disclosures	Part I. Item 4.	394
Executive Officers of Entergy Corporation	Part I and Part III. Item 10.	394
Market for Registrants’ Common Equity and Related Stockholder Matters	Part II. Item 5.	396
Selected Financial Data	Part II. Item 6.	397
Management’s Discussion and Analysis of Financial Condition and Results of Operations	Part II. Item 7.	398
Quantitative and Qualitative Disclosures About Market Risk	Part II. Item 7A.	398
Financial Statements and Supplementary Data	Part II. Item 8.	398
Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	Part II. Item 9.	398
Controls and Procedures	Part II. Item 9A.	398
Attestation Report of Registered Public Accounting Firm	Part II. Item 9A.	400
Directors and Executive Officers of the Registrants	Part III. Item 10.	408
Executive Compensation	Part III. Item 11.	413
Security Ownership of Certain Beneficial Owners and Management	Part III. Item 12.	475
Certain Relationships and Related Transactions and Director Independence	Part III. Item 13.	478
Principal Accountant Fees and Services	Part III. Item 14.	480
Exhibits and Financial Statement Schedules	Part IV. Item 15.	483
Signatures		484
Consents of Independent Registered Public Accounting Firm		492
Report of Independent Registered Public Accounting Firm		494
Index to Financial Statement Schedules		S-1
Exhibit Index		E-1

This combined Form 10-K is separately filed by Entergy Corporation and its seven “Registrant Subsidiaries”: Entergy Arkansas, Inc., Entergy Gulf States Louisiana, L.L.C., Entergy Louisiana, LLC, Entergy Mississippi, Inc., Entergy New Orleans, Inc., Entergy Texas, Inc., and System Energy Resources, Inc. Information contained herein relating to any individual company is filed by such company on its own behalf. Each company makes representations only as to itself and makes no other representations whatsoever as to any other company.

The report should be read in its entirety as it pertains to each respective reporting company. No one section of the report deals with all aspects of the subject matter. Separate Item 6, 7, and 8 sections are provided for each reporting company, except for the Notes to the financial statements. The Notes to the financial statements for all of the reporting companies are combined. All Items other than 6, 7, and 8 are combined for the reporting companies.

iii

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FORWARD-LOOKING INFORMATION

In this combined report and from time to time, Entergy Corporation and the Registrant Subsidiaries each makes statements as a registrant concerning its expectations, beliefs, plans, objectives, goals, strategies, and future events or performance. Such statements are "forward-looking statements" within the meaning of the Private Securities Litigation Reform Act of 1995. Words such as "may," "will," "could," "project," "believe," "anticipate," "intend," "expect," "estimate," "continue," "potential," "plan," "predict," "forecast," and other similar words or expressions are intended to identify forward-looking statements but are not the only means to identify these statements. Although each of these registrants believes that these forward-looking statements and the underlying assumptions are reasonable, it cannot provide assurance that they will prove correct. Any forward-looking statement is based on information current as of the date of this combined report and speaks only as of the date on which such statement is made. Except to the extent required by the federal securities laws, these registrants undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events, or otherwise.

Forward-looking statements involve a number of risks and uncertainties. There are factors that could cause actual results to differ materially from those expressed or implied in the forward-looking statements, including those factors discussed or incorporated by reference in (a) Item 1A. Risk Factors, (b) Management's Financial Discussion and Analysis, and (c) the following factors (in addition to others described elsewhere in this combined report and in subsequent securities filings):

·	resolution of pending and future rate cases and negotiations, including various performance-based rate discussions, Entergy's utility supply plan, and recovery of fuel and purchased power costs;

·	the termination of Entergy Arkansas’s and Entergy Mississippi’s participation in the System Agreement in December 2013 and November 2015, respectively;

·	regulatory and operating challenges and uncertainties associated with the Utility operating companies’ proposal to move to the MISO RTO and the scheduled expiration of the current independent coordinator of transmission arrangement in November 2012;

changes in utility regulation, including the beginning or end of retail and wholesale competition, the ability to recover net utility assets and other potential stranded costs, the operations of the independent coordinator of transmission for Entergy's utility service territory, and the application of more stringent transmission reliability requirements or market power criteria by the FERC;

changes in regulation of nuclear generating facilities and nuclear materials and fuel, including possible shutdown of nuclear generating facilities, particularly those owned or operated by the Entergy Wholesale Commodities business, and the effects of new or existing safety concerns regarding nuclear power plants and nuclear fuel;

·	resolution of pending or future applications, and related regulatory proceedings and litigation, for license renewals or modifications of nuclear generating facilities;

·	the performance of and deliverability of power from Entergy's generation resources, including the capacity factors at its nuclear generating facilities;

·	Entergy's ability to develop and execute on a point of view regarding future prices of electricity, natural gas, and other energy-related commodities;

·	prices for power generated by Entergy's merchant generating facilities and the ability to hedge, sell power forward or otherwise reduce the market price risk associated with those facilities, including the Entergy Wholesale Commodities nuclear plants;

·	the prices and availability of fuel and power Entergy must purchase for its Utility customers, and Entergy's ability to meet credit support requirements for fuel and power supply contracts;

·	volatility and changes in markets for electricity, natural gas, uranium, and other energy-related commodities;

·	changes in law resulting from federal or state energy legislation or legislation subjecting energy derivatives used in hedging and risk management transactions to governmental regulation;

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FORWARD-LOOKING INFORMATION (Concluded)

·	changes in environmental, tax, and other laws, including requirements for reduced emissions of sulfur, nitrogen, carbon, mercury, and other substances, and changes in costs of compliance with environmental and other laws and regulations;

·	uncertainty regarding the establishment of interim or permanent sites for spent nuclear fuel and nuclear waste storage and disposal;

risks associated with the proposed spin-off and subsequent merger of Entergy’s electric transmission business into a subsidiary of ITC Holdings Corp., including the risk that Entergy and the Utility operating companies may not be able to timely satisfy the conditions or obtain the approvals required to complete such transaction or such approvals may contain material restrictions or conditions, and the risk that if completed, the transaction may not be achieve its anticipated results;

variations in weather and the occurrence of hurricanes and other storms and disasters, including uncertainties associated with efforts to remediate the effects of hurricanes, ice storms, or other weather events and the recovery of costs associated with restoration, including accessing funded storm reserves, federal and local cost recovery mechanisms, securitization, and insurance;

·	effects of climate change;

·	Entergy's ability to manage its capital projects and operation and maintenance costs;

·	Entergy's ability to purchase and sell assets at attractive prices and on other attractive terms;

·	the economic climate, and particularly economic conditions in Entergy's Utility service territory and the Northeast United States and events that could influence economic conditions in those areas;

·	the effects of Entergy's strategies to reduce tax payments;

·	changes in the financial markets, particularly those affecting the availability of capital and Entergy's ability to refinance existing debt, execute share repurchase programs, and fund investments and acquisitions;

·	actions of rating agencies, including changes in the ratings of debt and preferred stock, changes in general corporate ratings, and changes in the rating agencies' ratings criteria;

·	changes in inflation and interest rates;

·	the effect of litigation and government investigations or proceedings;

·	advances in technology;

·	the potential effects of threatened or actual terrorism, cyber attacks or data security breaches, and war or a catastrophic event such as a nuclear accident or a natural gas pipeline explosion;

·	Entergy's ability to attract and retain talented management and directors;

·	changes in accounting standards and corporate governance;

·	declines in the market prices of marketable securities and resulting funding requirements for Entergy's defined benefit pension and other postretirement benefit plans;

·	changes in decommissioning trust fund values or earnings or in the timing of or cost to decommission nuclear plant sites;

·	factors that could lead to impairment of long-lived assets; and

·	the ability to successfully complete merger, acquisition, or divestiture plans, regulatory or other limitations imposed as a result of merger, acquisition, or divestiture, and the success of the business following a merger, acquisition, or divestiture.

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DEFINITIONS

Certain abbreviations or acronyms used in the text and notes are defined below:

Abbreviation or Acronym	Term

AFUDC	Allowance for Funds Used During Construction
ALJ	Administrative Law Judge
ANO 1 and 2	Units 1 and 2 of Arkansas Nuclear One (nuclear), owned by Entergy Arkansas
APSC	Arkansas Public Service Commission
ASU	Accounting Standards Update issued by the FASB
Board	Board of Directors of Entergy Corporation
Cajun	Cajun Electric Power Cooperative, Inc.
bundled energy and capacity contract	A contract for the sale of installed capacity and related energy, priced per megawatt-hour sold
capacity contract	A contract for the sale of the installed capacity product in regional markets managed by ISO New England and the New York Independent System Operator
capacity factor	Actual plant output divided by maximum potential plant output for the period
City Council or Council	Council of the City of New Orleans, Louisiana
DOE	United States Department of Energy
D. C. Circuit	U.S. Court of Appeals for the District of Columbia
Entergy	Entergy Corporation and its direct and indirect subsidiaries
Entergy Corporation	Entergy Corporation, a Delaware corporation
Entergy Gulf States, Inc.	Predecessor company for financial reporting purposes to Entergy Gulf States Louisiana that included the assets and business operations of both Entergy Gulf States Louisiana and Entergy Texas
Entergy Gulf States Louisiana	Entergy Gulf States Louisiana, L.L.C., a company formally created as part of the jurisdictional separation of Entergy Gulf States, Inc. and the successor company to Entergy Gulf States, Inc. for financial reporting purposes. The term is also used to refer to the Louisiana jurisdictional business of Entergy Gulf States, Inc., as the context requires.
Entergy-Koch	A joint venture equally owned by subsidiaries of Entergy and Koch Industries, Inc. Entergy-Koch’s pipeline and trading businesses were sold in 2004.
Entergy Texas	Entergy Texas, Inc., a company formally created as part of the jurisdictional separation of Entergy Gulf States, Inc. The term is also used to refer to the Texas jurisdictional business of Entergy Gulf States, Inc., as the context requires.
Entergy Wholesale Commodities (EWC)	Entergy’s non-utility business segment primarily comprised of the ownership and operation of six nuclear power plants, the ownership of interests in non-nuclear power plants, and the sale of the electric power produced by those plants to wholesale customers
EPA	United States Environmental Protection Agency
ERCOT	Electric Reliability Council of Texas
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
firm LD	Transaction that requires receipt or delivery of energy at a specified delivery point (usually at a market hub not associated with a specific asset) or settles financially on notional quantities; if a party fails to deliver or receive energy, the defaulting party must compensate the other party as specified in the contract
FitzPatrick	James A. FitzPatrick Nuclear Power Plant (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
Grand Gulf	Unit No. 1 of Grand Gulf Nuclear Station (nuclear), 90% owned or leased by System Energy
GWh	Gigawatt-hour(s), which equals one million kilowatt-hours

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DEFINITIONS (Continued)

Abbreviation or Acronym		Term

Independence		Independence Steam Electric Station (coal), owned 16% by Entergy Arkansas, 25% by Entergy Mississippi, and 7% by Entergy Power
Indian Point 2		Unit 2 of Indian Point Energy Center (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
Indian Point 3		Unit 3 of Indian Point Energy Center (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
IRS		Internal Revenue Service
ISO		Independent System Operator
kV		Kilovolt
kW		Kilowatt, which equals one thousand watts
kWh		Kilowatt-hour(s)
LDEQ		Louisiana Department of Environmental Quality
LPSC		Louisiana Public Service Commission
Mcf		1,000 cubic feet of gas
MISO		Midwest Independent Transmission System Operator, Inc., a regional transmission organization
MMBtu		One million British Thermal Units
MPSC		Mississippi Public Service Commission
MW		Megawatt(s), which equals one thousand kilowatt(s)
MWh		Megawatt-hour(s)
Nelson Unit 6		Unit No. 6 (coal) of the Nelson Steam Electric Generating Station, 70% of which is co-owned by Entergy Gulf States Louisiana (57.5%) and Entergy Texas (42.5%), and 10.9% of which is owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
Net debt ratio		Gross debt less cash and cash equivalents divided by total capitalization less cash and cash equivalents
Net MW in operation		Installed capacity owned and operated
NRC		Nuclear Regulatory Commission
NYPA		New York Power Authority
OASIS		Open Access Same Time Information Systems
Offsetting positions		Transactions for the purchase of energy, generally to offset a firm LD transaction
Palisades		Palisades Power Plant (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
percent of capacity sold forward		Percent of planned qualified capacity sold to mitigate price uncertainty under physical or financial transactions
percent of planned generation sold forward		Percent of planned generation output sold or purchased forward under contracts, forward physical contracts, forward financial contracts or options that mitigate price uncertainty that may or may not require regulatory approval
Pilgrim		Pilgrim Nuclear Power Station (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
planned net MW in operation		Amount of capacity to be available to generate power and/or sell capacity considering uprates planned to be completed during the year
PPA		Purchased power agreement or power purchase agreement
PRP		Potentially responsible party (a person or entity that may be responsible for remediation of environmental contamination)
PUCT		Public Utility Commission of Texas
Registrant Subsidiaries		Entergy Arkansas, Inc., Entergy Gulf States Louisiana, L.L.C., Entergy Louisiana, LLC, Entergy Mississippi, Inc., Entergy New Orleans, Inc., Entergy Texas, Inc., and System Energy Resources, Inc.

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DEFINITIONS (Concluded)

Abbreviation or Acronym	Term

Ritchie Unit 2	Unit 2 of the R.E. Ritchie Steam Electric Generating Station (gas/oil)
River Bend	River Bend Station (nuclear), owned by Entergy Gulf States Louisiana
RTO	Regional transmission organization
SEC	Securities and Exchange Commission
SMEPA	South Mississippi Electric Power Association, which owns a 10% interest in Grand Gulf
System Agreement	Agreement, effective January 1, 1983, as modified, among the Utility operating companies relating to the sharing of generating capacity and other power resources
System Energy	System Energy Resources, Inc.
System Fuels	System Fuels, Inc.
TWh	Terawatt-hour(s), which equals one billion kilowatt-hours
UK	United Kingdom of Great Britain and Northern Ireland
unit-contingent	Transaction under which power is supplied from a specific generation asset; if the asset is not operating, the seller is generally not liable to the buyer for any damages
Unit Power Sales Agreement	Agreement, dated as of June 10, 1982, as amended and approved by FERC, among Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy, relating to the sale of capacity and energy from System Energy’s share of Grand Gulf
Utility	Entergy’s business segment that generates, transmits, distributes, and sells electric power, with a small amount of natural gas distribution
Utility operating companies	Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas
Vermont Yankee	Vermont Yankee Nuclear Power Station (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
Waterford 3	Unit No. 3 (nuclear) of the Waterford Steam Electric Station, 100% owned or leased by Entergy Louisiana
weather-adjusted usage	Electric usage excluding the effects of deviations from normal weather
White Bluff	White Bluff Steam Electric Generating Station, 57% owned by Entergy Arkansas

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ENTERGY CORPORATION AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Entergy operates primarily through two business segments: Utility and Entergy Wholesale Commodities.

The Utility business segment includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operates a small natural gas distribution business. As discussed in more detail in “Plan to Spin Off the Utility’s Transmission Business,” in December 2011, Entergy entered into an agreement to spin off its transmission business and merge it with a newly-formed subsidiary of ITC Holdings Corp.

The Entergy Wholesale Commodities business segment includes the ownership and operation of six nuclear power plants located in the northern United States and the sale of the electric power produced by those plants to wholesale customers. This business also provides services to other nuclear power plant owners. Entergy Wholesale Commodities also owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.

Following are the percentages of Entergy’s consolidated revenues and net income generated by its operating segments and the percentage of total assets held by them:

	% of Revenue			% of Net Income			% of Total Assets
Segment	2011	2010	2009	2011	2010	2009	2011	2010	2009

Utility	79	78	75	82	65	57	80	80	80
Entergy Wholesale Commodities	21	22	25	36	39	51	26	26	30
Parent & Other	-	-	-	(18)	(4)	(8)	(6)	(6)	(10)

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Results of Operations

2011 Compared to 2010

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing 2011 to 2010 showing how much the line item increased or (decreased) in comparison to the prior period:

	Utility	Entergy Wholesale Commodities	Parent & Other	Entergy
	(In Thousands)

2010 Consolidated Net Income (Loss)	$829,719	$489,422	($48,836)	$1,270,305

Net revenue (operating revenue less fuel expense, purchased power, and other regulatory charges/credits)	(146,947)	(155,898)	3,620	(299,225)
Other operation and maintenance expenses	1,674	(141,588)	38,270	(101,644)
Taxes other than income taxes	248	1,083	396	1,727
Depreciation and amortization	16,326	16,008	(26)	32,308
Gain on sale of business	-	(44,173)	-	(44,173)
Other income	(3,388)	(39,717)	1,799	(41,306)
Interest expense	(37,502)	(51,183)	27,145	(61,540)
Other	1,688	(23,334)	-	(21,646)
Income taxes (benefit)	(426,916)	(43,193)	139,133	(330,976)

2011 Consolidated Net Income (Loss)	$1,123,866	$491,841	($248,335)	$1,367,372

Refer to “SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON OF ENTERGY CORPORATION AND SUBSIDIARIES” which accompanies Entergy Corporation’s financial statements in this report for further information with respect to operating statistics.

Net income for Utility in 2011 was significantly affected by a settlement with the IRS related to the mark-to-market income tax treatment of power purchase contracts, which resulted in a reduction in income tax expense. The net income effect was partially offset by a regulatory charge, which reduced net revenue, because a portion of the benefits will be shared with customers. See Notes 3 and 8 to the financial statements for additional discussion of the settlement and benefit sharing.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Net Revenue

Utility

Following is an analysis of the change in net revenue comparing 2011 to 2010.

		Amount
		(In Millions)

2010 net revenue		$5,051
Mark-to-market tax settlement sharing		(196)
Purchased power capacity		(21)
Net wholesale revenue		(14)
Volume/weather		13
ANO decommissioning trust		24
Retail electric price		49
Other		(2)
2011 net revenue		$4,904

The mark-to-market tax settlement sharing variance results from a regulatory charge because a portion of the benefits of a settlement with the IRS related to the mark-to-market income tax treatment of power purchase contracts will be shared with customers, slightly offset by the amortization of a portion of that charge beginning in October 2011. See Notes 3 and 8 to the financial statements for additional discussion of the settlement and benefit sharing.

The purchased power capacity variance is primarily due to price increases for ongoing purchased power capacity and additional capacity purchases.

The net wholesale revenue variance is primarily due to lower margins on co-owner contracts and higher wholesale energy costs.

The volume/weather variance is primarily due to an increase of 2,061 GWh in weather-adjusted usage across all sectors. Weather-adjusted residential retail sales growth reflected an increase in the number of customers. Industrial sales growth has continued since the beginning of 2010. Entergy’s service territory has benefited from the national manufacturing economy and exports, as well as industrial facility expansions. Increases have been offset to some extent by declines in the paper, wood products, and pipeline segments. The increase was also partially offset by the effect of less favorable weather on residential sales.

The ANO decommissioning trust variance is primarily related to the deferral of investment gains from the ANO 1 and 2 decommissioning trust in 2010 in accordance with regulatory treatment. The gains resulted in an increase in interest and investment income in 2010 and a corresponding increase in regulatory charges with no effect on net income.

The retail electric price variance is primarily due to:

·	rate actions at Entergy Texas, including a base rate increase effective August 2010 and an additional increase beginning May 2011;

·	a formula rate plan increase at Entergy Louisiana effective May 2011; and

·	a base rate increase at Entergy Arkansas effective July 2010.

These were partially offset by formula rate plan decreases at Entergy New Orleans effective October 2010 and October 2011. See Note 2 to the financial statements for further discussion of these proceedings.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Entergy Wholesale Commodities

Following is an analysis of the change in net revenue comparing 2011 to 2010.

		Amount
		(In Millions)

2010 net revenue		$2,200
Realized price changes		(159)
Fuel expenses		(30)
Harrison County		(27)
Volume		60
2011 net revenue		$2,044

As shown in the table above, net revenue for Entergy Wholesale Commodities decreased by $156 million, or 7%, in 2011 compared to 2010 primarily due to:

·	lower pricing in its contracts to sell power;

·	higher fuel expenses, primarily at the nuclear plants; and

·	the absence of the Harrison County plant, which was sold in December 2010.

These factors were partially offset by higher volume resulting from fewer planned and unplanned outage days in 2011 compared to the same period in 2010.

Following are key performance measures for Entergy Wholesale Commodities for 2011 and 2010:

	2011	2010

Owned capacity	6,599	6,351
GWh billed	43,520	42,682
Average realized price per MWh	$54.48	$59.04

Entergy Wholesale Commodities Nuclear Fleet
Capacity factor	93%	90%
GWh billed	40,918	39,655
Average realized revenue per MWh	$54.73	$59.16
Refueling Outage Days:
FitzPatrick	-	35
Indian Point 2	-	33
Indian Point 3	30	-
Palisades	-	26
Pilgrim	25	-
Vermont Yankee	25	29

Realized Revenue per MWh for Entergy Wholesale Commodities Nuclear Plants

The recent economic downturn and negative trends in the energy commodity markets have resulted in lower natural gas prices and therefore lower market prices for electricity in the New York and New England power regions, which is where five of the six Entergy Wholesale Commodities nuclear power plants are located. Entergy Wholesale Commodities’ nuclear business experienced a decrease in realized price per MWh to $54.73 in 2011 from $59.16 in 2010, and is likely to experience a decrease again in 2012 because, as shown in the contracted sale of energy table in “Market and Credit Risk Sensitive Instruments,” Entergy Wholesale Commodities has sold forward 88% of its planned nuclear energy output for 2012 for an average contracted energy price of $49 per MWh. In addition, Entergy Wholesale Commodities has sold forward 81% of its planned energy output for 2013 for an average contracted energy price range of $45-50 per MWh.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Other Income Statement Items

Utility

Other operation and maintenance expenses increased from $1,949 million for 2010 to $1,951 million for 2011 primarily due to:

·	an increase of $17 million in nuclear expenses primarily due to higher labor costs, including higher contract labor;

·	an increase of $15 million in contract costs due to the transition and implementation of joining the MISO RTO;

·	an increase of $9 million in legal expenses primarily resulting from an increase in legal and regulatory activity increasing the use of outside legal services;

·	an increase of $8 million in fossil-fueled generation expenses primarily due to the addition of Acadia Unit 2 in April 2011; and

·	several individually insignificant items.

These increases were substantially offset by:

a decrease of $29 million in compensation and benefits costs primarily resulting from an increase in the accrual for incentive-based compensation in 2010 and a decrease in stock option expense. The decrease in stock option expense is offset by credits recorded by the parent company, Entergy Corporation;

the deferral in 2011 of $13.4 million of 2010 Michoud plant maintenance costs pursuant to the settlement of Entergy New Orleans’ 2010 test year formula rate plan filing approved by the City Council in September 2011. See Note 2 to the financial statements for further discussion of the 2010 test year formula rate plan filing and settlement;

·	the amortization of $11 million of Entergy Texas rate case expenses in 2010. See Note 2 to the financial statements for further discussion of the Entergy Texas rate case settlement; and

·	a decrease of $10 million in operating expenses due to the sale of surplus oil inventory in 2011.

Depreciation and amortization expense increased primarily due to an increase in plant in service, partially offset by a decrease in depreciation rates at Entergy Arkansas as a result of the rate case settlement agreement approved by the APSC in June 2010.

Interest expense decreased primarily due to:

·	the refinancing of long-term debt at lower interest rates by certain of the Utility operating companies;

·	a revision caused by FERC’s acceptance of a change in the treatment of funds received from independent power producers for transmission interconnection projects; and

·	interest expense accrued in 2010 related to the expected result of the LPSC Staff audit of Entergy Gulf States Louisiana’s fuel adjustment clause for the period 1995 through 2004.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Entergy Wholesale Commodities

Other operation and maintenance expenses decreased from $1,047 million for 2010 to $905 million for 2011 primarily due to:

·	the write-off of $64 million of capital costs in 2010, primarily for software that would not be utilized, and $16 million of additional costs incurred in 2010 in connection with Entergy’s decision to unwind the infrastructure created for the planned spin-off of its non-utility nuclear business;

·	a decrease of $30 million due to the absence of expenses from the Harrison County plant, which was sold in December 2010;

·	a decrease in compensation and benefits costs resulting from an increase of $19 million in the accrual for incentive-based compensation in 2010;

·	a decrease of $12 million in spending on tritium remediation work; and

·	the write-off of $10 million of capitalized engineering costs in 2010 associated with a potential uprate project.

The gain on sale resulted from the sale in 2010 of Entergy’s ownership interest in the Harrison County Power Project 550 MW combined-cycle plant to two Texas electric cooperatives that owned a minority share of the plant. Entergy sold its 61 percent share of the plant for $219 million and realized a pre-tax gain of $44.2 million on the sale.

Depreciation and amortization expense increased primarily due to an increase in plant in service and declining useful life of nuclear assets.

Other income decreased primarily due to a decrease in interest income earned on loans to the parent company, Entergy Corporation, and a decrease of $13 million in realized earnings on decommissioning trust fund investments.

Interest expense decreased primarily due to the write-off of $39 million of debt financing costs in 2010, primarily incurred for a $1.2 billion credit facility that will not be used, in connection with Entergy’s decision to unwind the infrastructure created for the planned spin-off of its non-utility nuclear business.

Other expenses decreased primarily due to a credit to decommissioning expense of $34.1 million in 2011 resulting from a reduction in the decommissioning liability for a plant as a result of a revised decommissioning cost study obtained to comply with a state regulatory requirement. See “Critical Accounting Estimates – Nuclear Decommissioning Costs” below for further discussion of accounting for asset retirement obligations.

Parent & Other

Other operation and maintenance expenses increased primarily due to lower intercompany stock option credits recorded by the parent company, Entergy Corporation, and an increase of $13 million related to the planned spin-off and merger of Entergy’s transmission business. See “Plan to Spin Off the Utility’s Transmission Business” below for further discussion.

Interest expense increased primarily due to $1 billion of Entergy Corporation senior notes issued in September 2010, with the proceeds used to pay down borrowings outstanding on Entergy Corporation’s revolving credit facility that were at a lower interest rate.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Income Taxes

The effective income tax rate for 2011 was 17.3%. The difference in the effective income tax rate versus the statutory rate of 35% in 2011 was primarily due to a settlement with the IRS related to the mark-to-market income tax treatment of power purchase contracts, which resulted in a reduction in income tax expense of $422 million. See Note 3 to the financial statements herein for further discussion of the settlement.

The effective income tax rate for 2010 was 32.7%. The difference in the effective income tax rate versus the statutory rate of 35% in 2010 was primarily due to:

a favorable Tax Court decision holding that the U.K. Windfall Tax may be used as a credit for purposes of computing the U.S. foreign tax credit, which allowed Entergy to reverse a provision for uncertain tax positions of $43 million, included in Parent and Other, on the issue. See Note 3 to the financial statements for further discussion of this tax litigation;

·	a $19 million tax benefit recorded in connection with Entergy’s decision to unwind the infrastructure created for the planned spin-off of its non-utility nuclear business; and

·	the recognition of a $14 million Louisiana state income tax benefit related to storm cost financing.

Partially offsetting the decreased effective income tax rate was a charge of $16 million resulting from a change in tax law associated with the recently enacted federal healthcare legislation, as discussed below in “Critical Accounting Estimates” and state income taxes and certain book and tax differences for Utility plant items.

See Note 3 to the financial statements for a reconciliation of the federal statutory rate of 35.0% to the effective income tax rates, and for additional discussion regarding income taxes.

2010 Compared to 2009

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing 2010 to 2009 showing how much the line item increased or (decreased) in comparison to the prior period:

	Utility	Entergy Wholesale Commodities	Parent & Other	Entergy
	(In Thousands)

2009 Consolidated Net Income (Loss)	$708,905	$641,094	($98,949)	$1,251,050

Net revenue (operating revenue less fuel expense, purchased power, and other regulatory charges/credits)	357,211	(163,518)	8,622	202,315
Other operation and maintenance expenses	112,384	124,758	(18,550)	218,592
Taxes other than income taxes	28,872	2,717	(1,149)	30,440
Depreciation and amortization	(24,112)	11,413	(182)	(12,881)
Gain on sale of business	-	44,173	-	44,173
Other income	(14,915)	66,222	(25,681)	25,626
Interest expense	31,035	(6,461)	(19,851)	4,723
Other	7,758	19,728	-	27,486
Income taxes	65,545	(53,606)	(27,440)	(15,501)

2010 Consolidated Net Income (Loss)	$829,719	$489,422	($48,836)	$1,270,305

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

In November 2007 the Board approved a plan to pursue a separation of Entergy’s non-utility nuclear business from Entergy through a spin-off of the business to Entergy shareholders. In April 2010, Entergy announced that it planned to unwind the business infrastructure associated with the proposed spin-off transaction. As a result of the plan to unwind the business infrastructure, Entergy recorded expenses in 2010 for the write-off of certain capitalized costs incurred in connection with the planned spin-off transaction. These costs are discussed in more detail below and throughout this section.

Net Revenue

Utility

Following is an analysis of the change in net revenue comparing 2010 to 2009.

		Amount
		(In Millions)

2009 net revenue		$4,694
Volume/weather		231
Retail electric price		137
Provision for regulatory proceedings		26
Rough production cost equalization		19
ANO decommissioning trust		(24)
Fuel recovery		(44)
Other		12
2010 net revenue		$5,051

The volume/weather variance is primarily due to an increase of 8,362 GWh, or 8%, in billed electricity usage in all retail sectors, including the effect on the residential sector of colder weather in the first quarter 2010 compared to 2009 and warmer weather in the second and third quarters 2010 compared to 2009. The industrial sector reflected strong sales growth on continuing signs of economic recovery. The improvement in this sector was primarily driven by inventory restocking and strong exports with the chemicals, refining, and miscellaneous manufacturing sectors leading the improvement.

The retail electric price variance is primarily due to:

·	increases in the formula rate plan riders at Entergy Gulf States Louisiana effective November 2009, January 2010, and September 2010, at Entergy Louisiana effective November 2009, and at Entergy Mississippi effective July 2009;

·	a base rate increase at Entergy Arkansas effective July 2010;

·	rate actions at Entergy Texas, including base rate increases effective in May and August 2010;

·	a formula rate plan provision of $16.6 million recorded in the third quarter 2009 for refunds that were made to customers in accordance with settlements approved by the LPSC; and

·	the recovery in 2009 by Entergy Arkansas of 2008 extraordinary storm costs, as approved by the APSC, which ceased in January 2010. The recovery of storm costs is offset in other operation and maintenance expenses.

See Note 2 to the financial statements for further discussion of the proceedings referred to above.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

The provision for regulatory proceedings variance is primarily due to provisions recorded in 2009 at Entergy Arkansas. See Note 2 to the financial statements for a discussion of regulatory proceedings affecting Entergy Arkansas.

The rough production cost equalization variance is due to an additional $18.6 million allocation recorded in the second quarter of 2009 for 2007 rough production cost equalization receipts ordered by the PUCT to Texas retail customers over what was originally allocated to Entergy Texas prior to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 2007, as discussed in Note 2 to the financial statements.

The fuel recovery variance resulted primarily from an adjustment to deferred fuel costs in the fourth quarter 2009 relating to unrecovered nuclear fuel costs incurred since January 2008 that will now be recovered after a revision to the fuel adjustment clause methodology.

Entergy Wholesale Commodities

Following is an analysis of the change in net revenue comparing 2010 to 2009.

		Amount
		(In Millions)

2009 net revenue		$2,364
Nuclear realized price changes		(96)
Nuclear volume		(60)
Other		(8)
2010 net revenue		$2,200

As shown in the table above, net revenue for Entergy Wholesale Commodities decreased by $164 million, or 7%, in 2010 compared to 2009 primarily due to results from its nuclear operations. The net revenue decrease was primarily due to lower pricing in its contracts to sell nuclear power and lower nuclear volume resulting from more planned and unplanned outage days in 2010. Included in net revenue is $46 million and $53 million of amortization of the Palisades purchased power agreement in 2010 and 2009, respectively, which is non-cash revenue and is discussed in Note 15 to the financial statements. Following are key performance measures for Entergy Wholesale Commodities’ nuclear plants for 2010 and 2009:

	2010	2009

Net MW in operation at December 31	4,998	4,998
Average realized revenue per MWh	$59.16	$61.07
GWh billed	39,655	40,981
Capacity factor	90%	93%
Refueling Outage Days:
FitzPatrick	35	-
Indian Point 2	33	-
Indian Point 3	-	36
Palisades	26	41
Pilgrim	-	31
Vermont Yankee	29	-

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Overall, including its non-nuclear plants, Entergy Wholesale Commodities billed 42,682 GWh in 2010 and 43,969 GWh in 2009, with average realized revenue per MWh of $59.04 in 2010 and $60.46 in 2009.

Other Income Statement Items

Utility

Other operation and maintenance expenses increased from $1,837 million for 2009 to $1,949 million for 2010 primarily due to:

an increase of $70 million in compensation and benefits costs, resulting from decreasing discount rates, the amortization of benefit trust asset losses, and an increase in the accrual for incentive-based compensation. See “Critical Accounting Estimates - Qualified Pension and Other Postretirement Benefits” below and also Note 11 to the financial statements for further discussion of benefits costs;

·	an increase of $25 million in fossil-fueled generation expenses resulting from higher outage costs in 2010 primarily because the scope of the outages was greater than in 2009;

·	an increase of $17 million in transmission and distribution expenses resulting from increased vegetation contract work;

·	an increase of $13 million in nuclear expenses primarily due to higher nuclear labor and contract costs;

·	an increase of $12.5 million due to the capitalization in 2009 of Ouachita Plant service charges previously expensed; and

·	an increase of $11 million due to the amortization of Entergy Texas rate case expenses. See Note 2 to the financial statements for further discussion of the Entergy Texas rate case settlement.

The increase was partially offset by:

·	a decrease of $19.4 million due to 2008 storm costs at Entergy Arkansas which were deferred per an APSC order and were recovered through revenues in 2009;

·	a decrease of $16 million due to higher write-offs of uncollectible customer accounts in 2009; and

·	charges of $14 million in 2009 due to the Hurricane Ike and Hurricane Gustav storm cost recovery settlement agreement, as discussed further in Note 2 to the financial statements.

Other income decreased primarily due to:

·	a decrease of $50 million in carrying charges on storm restoration costs because of the completion of financing or securitization of the costs, as discussed further in Note 2 to the financial statements; and

·	a gain of $16 million recorded in 2009 on the sale of undeveloped real estate by Entergy Louisiana Properties, LLC.

The decrease was partially offset by:

·	an increase of $24 million due to investment gains from the ANO 1 and 2 decommissioning trust, as discussed above;

·	an increase of $14 million resulting from higher earnings on decommissioning trust funds; and

an increase of distributions of $13 million earned by Entergy Louisiana and $7 million earned by Entergy Gulf States Louisiana on investments in preferred membership interests of Entergy Holdings Company. The distributions on preferred membership interests are eliminated in consolidation and have no effect on net income because the investment is in another Entergy subsidiary. See Note 2 to the financial statements for discussion of these investments in preferred membership interests.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Interest expense increased primarily due to an increase in long-term debt outstanding resulting from net debt issuances by certain of the Utility operating companies in the second half of 2009 and in 2010. See Notes 4 and 5 to the financial statements for details of long-term debt outstanding.

Depreciation and amortization expenses decreased primarily due to a decrease in depreciation rates at Entergy Arkansas as a result of the rate case settlement agreement approved by the APSC in June 2010.

Entergy Wholesale Commodities

Other operation and maintenance expenses increased from $922 million for 2009 to $1,047 million for 2010 primarily due to:

·	the write-off of $64 million of capital costs, primarily for software that will not be utilized, and $16 million of additional costs incurred in connection with Entergy’s decision to unwind the infrastructure created for the planned spin-off of its non-utility nuclear business;

an increase of $36 million in compensation and benefits costs, resulting from decreasing discount rates, the amortization of benefit trust asset losses, and an increase in the accrual for incentive-based compensation. See “Critical Accounting Estimates - Qualified Pension and Other Postretirement Benefits” below and also Note 11 to the financial statements for further discussion of benefits costs;

·	spending of $15 million related to tritium remediation work at the Vermont Yankee site; and

·	the write-off of $10 million of capitalized engineering costs associated with a potential uprate project.

The gain on sale resulted from the sale of Entergy’s ownership interest in the Harrison County Power Project 550 MW combined-cycle plant to two Texas electric cooperatives that owned a minority share of the plant. Entergy sold its 61 percent share of the plant for $219 million and realized a pre-tax gain of $44.2 million on the sale.

Other income increased primarily due to $86 million in charges in 2009 resulting from the recognition of impairments that are not considered temporary of certain equity securities held in Entergy Wholesale Commodities’ decommissioning trust funds, partially offset by a decrease of $28 million in realized earnings on the decommissioning trust funds.

Interest expense decreased primarily due to a decrease in fees paid to Entergy Corporation for providing collateral in the form of guarantees in connection with some of the Entergy Wholesale Commodities agreements to sell power. The guarantee fees paid are intercompany transactions and are eliminated in consolidation. The decrease was substantially offset by the write-off of $39 million of debt financing costs, primarily incurred for a $1.2 billion credit facility that will not be used, in connection with Entergy’s decision to unwind the infrastructure created for the planned spin-off of its non-utility nuclear business.

Parent & Other

Other income decreased primarily due to increases in the distributions paid of $13 million to Entergy Louisiana and $7 million to Entergy Gulf States Louisiana on investments in preferred membership interests of Entergy Holdings Company, as discussed above.

Interest expense decreased primarily due to lower borrowings, including the redemption of $267 million of notes payable in December 2009, as well as lower interest rates on borrowings under Entergy Corporation’s revolving credit facility.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Income Taxes

The effective income tax rate for 2010 was 32.7%. The difference in the effective income tax rate versus the statutory rate of 35% in 2010 was primarily due to:

·	a $19 million tax benefit recorded in connection with Entergy’s decision to unwind the infrastructure created for the planned spin-off of its non-utility nuclear business; and

·	the recognition of a $14 million Louisiana state income tax benefit related to storm cost financing.

The effective income tax rate for 2009 was 33.6%. The difference in the effective income tax rate versus the federal statutory rate of 35% in 2009 was primarily due to:

·	recognition of a capital loss of $73.1 million resulting from the sale of preferred stock of an Entergy Wholesale Commodities subsidiary to a third party;

·	reduction of a valuation allowance of $24.3 million on state loss carryovers;

·	reduction of a valuation allowance of $16.2 million on a federal capital loss carryover;

·	reduction of the provision for uncertain tax positions of $15.2 million resulting from settlements and agreements with taxing authorities;

·	adjustment to state income taxes of $13.8 million for Entergy Wholesale Commodities to reflect the effect of a change in the methodology of computing Massachusetts state income taxes as required by that state’s taxing authority; and

·	additional deferred tax benefit of approximately $8 million associated with writedowns on nuclear decommissioning qualified trust securities.

These reductions were partially offset by increases related to book and tax differences for utility plant items and state income taxes at the Utility operating companies.

See Note 3 to the financial statements for a reconciliation of the federal statutory rate of 35.0% to the effective income tax rates, and for additional discussion regarding income taxes.

Plan to Spin Off the Utility’s Transmission Business

On December 5, 2011, Entergy announced that it would spin off its transmission business and merge it with a newly formed subsidiary of ITC Holdings Corp. (ITC). In order to effect the spin-off and merger, Entergy entered into (i) a Merger Agreement with Mid South TransCo LLC, a newly formed, wholly owned subsidiary of Entergy (TransCo); ITC; and Ibis Transaction Subsidiary LLC (Merger Sub), a newly formed, wholly-owned subsidiary of ITC; and (ii) a Separation Agreement with TransCo, ITC, each of the Utility operating companies, and Entergy Services, Inc. These agreements, which have been approved by the Boards of Directors of Entergy and ITC, provide for the separation of Entergy’s transmission business (the “Transmission Business”), the distribution to Entergy’s stockholders of all of the common units of TransCo, a holding company subsidiary formed to hold the Transmission Business, and the merger of Merger Sub with and into TransCo, with TransCo continuing as the surviving entity in the Merger (the Merger), following which each common unit of TransCo will be converted into the right to receive one fully paid and nonassessable share of ITC common stock. Both the Distribution (as defined below) and the Merger are expected to qualify as tax-free transactions.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Pursuant to the Merger Agreement, and subject to the terms and conditions set forth therein, Entergy will distribute the TransCo common units to its shareholders. At Entergy’s election, it may distribute the TransCo common units by means of a pro rata dividend in a spin-off or pursuant to an exchange offer in a split-off, or a combination of a spin-off and a split-off (the Distribution). In connection with the Merger, ITC expects to effectuate a $700 million recapitalization, currently anticipated to take the form of a one-time special dividend to its shareholders of record as of a record date prior to the Merger, which will be determined by the board of directors of ITC at a later date (the Special Dividend). Entergy’s shareholders who become shareholders of ITC as a result of the Merger will not receive the Special Dividend. Pursuant to the Merger Agreement, and subject to the terms and conditions set forth therein, immediately after the consummation of the Separation (as defined below), the consummation of the Financings (as defined below), the payment of the Special Dividend and the consummation of the Distribution, Merger Sub will merge with and into TransCo, with TransCo continuing as the surviving entity, and Entergy shareholders who hold common units of TransCo will have those units exchanged for ITC common stock on a one-for-one basis. Consummation of the transactions contemplated by the Separation Agreement and the Merger Agreement is expected to result in Entergy’s shareholders holding at least 50.1% of ITC’s common stock and existing ITC shareholders holding no more than 49.9% of ITC’s common stock immediately after the Merger.

The Merger Agreement contains certain customary representations and warranties. The Merger Agreement may be terminated: (i) by mutual consent of Entergy and ITC, (ii) by either Entergy or ITC if the Merger has not been completed by June 30, 2013, subject to an up to six month extension by either Entergy or ITC in certain circumstances, (iii) by either Entergy or ITC if the transactions are enjoined or otherwise prohibited by applicable law, (iv) by Entergy, on the one hand, or ITC, on the other hand, upon a material breach of the Merger Agreement by the other party that has not been cured by the cure period specified in the Merger Agreement, (v) by either Entergy or ITC if ITC’s shareholders fail to approve the ITC shareholder proposals, (vi) by Entergy if the ITC Board of Directors withdraws or changes its recommendation of the ITC shareholder proposals in a manner adverse to Entergy, (vii) by Entergy if ITC willfully breaches in any material respect its non-solicitation covenant and the breach has not been cured by the cure period specified in the Merger Agreement, (viii) by Entergy if there is a law or order that enjoins the transactions or imposes a burdensome condition on Entergy, (ix) by either Entergy or ITC if there is a law or order that enjoins the transactions or imposes a burdensome condition on ITC, (x) by ITC, prior to ITC shareholder approval, to enter into a transaction for a superior proposal, provided that ITC complies with its notice and other obligations in the non-solicitation provision and pays Entergy the termination fee concurrently with termination or (xi) by ITC if Entergy takes certain actions with respect to the migration of the Transmission Business to a regional transmission organization if such actions could reasonably be expected to have certain adverse effects on TransCo or ITC after the Merger. In the event that (i) ITC terminates the Merger Agreement to accept a superior acquisition proposal, (ii) Entergy terminates the Merger Agreement because the ITC Board of Directors has withdrawn its recommendation of the ITC shareholder proposals, approves or recommends another acquisition proposal, fails to reaffirm its recommendation or materially breaches the non-solicitation provisions, (iii) either of the parties terminates the Merger Agreement because the approval of ITC’s shareholders is not obtained or (iv) Entergy terminates because of ITC’s uncured willful breach of the Merger Agreement, and in the case of clauses (iii) and (iv) an ITC takeover transaction was publicly announced and not withdrawn prior to termination and within 12 months of termination ITC agrees to or consummates a takeover transaction, then ITC must pay Entergy a $113,570,800 termination fee.

Consummation of the Merger is subject to the satisfaction of customary closing conditions for a transaction such as the Merger, including, among others, (i) consummation of the Separation, the Distribution, the Financings and the Special Dividend, (ii) the approval of the ITC shareholder proposals by the shareholders of ITC, (iii) the authorization for listing on the New York Stock Exchange of ITC common stock to be issued in the Merger, (iv) the receipt by Entergy of regulatory approvals necessary to become a member of an acceptable regional transmission organization, (v) the receipt of regulatory approvals necessary to consummate the transaction and the expiration of the applicable waiting period under the Hart-Scott-Rodino Act, and no such regulatory approvals impose a burdensome condition on ITC or Entergy, (vi) the absence of a material adverse effect on the Transmission Business or ITC, (vii) the receipt by Entergy of a solvency opinion and (viii) the receipt of a private letter ruling from the IRS substantially to the effect that certain requirements for the tax-free treatment of the distribution of TransCo are met and an opinion

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that the Distribution and the Merger will be treated as tax-free reorganizations for U.S. federal income tax purposes. The Merger and the other transactions contemplated by the Merger Agreement and the Separation Agreement are planned for completion in 2013.

Pursuant to the Separation Agreement, and subject to the terms and conditions set forth therein, Entergy will engage in a series of preliminary restructuring transactions that result in the transfer to TransCo’s subsidiaries of the assets relating to the Transmission Business (the Separation). TransCo and its subsidiaries will consummate certain financing transactions (the TransCo Financing) totaling approximately $1.775 billion pursuant to which (i) TransCo’s subsidiaries will borrow through a one-year term funded bridge facility and (ii) TransCo will issue senior securities of TransCo to Entergy (the TransCo Securities). Neither Entergy nor the Utility operating companies will guarantee or otherwise be liable for the payment of the TransCo Securities. Entergy will issue new debt or enter into agreements under which certain unrelated creditors will agree to purchase existing corporate debt of Entergy, which will be exchangeable into the TransCo Securities at closing (the Exchangeable Debt Financing). In addition, prior to the closing TransCo may obtain a working capital revolving credit facility in a principal amount agreed to by Entergy and ITC (such financing, together with the TransCo Financing and the Exchangeable Debt Financing, the Financings).

Under the terms of the Separation Agreement, concurrently with the TransCo Financing, each Utility operating company will contribute its respective transmission assets to a subsidiary that will become a TransCo subsidiary in the Separation in exchange for the equity interest in that subsidiary and the net proceeds received by that subsidiary from the one-year funded bridge facility described above. Each Utility operating company will distribute the equity interests in the subsidiaries holding the transmission assets to Entergy, which will then contribute such interests to TransCo. The Utility operating companies intend to apply all or a portion of the amounts received by them from the subsidiaries to the prepayment or redemption of outstanding preferred and debt securities, with the goal, following completion of the Separation, of maintaining their capitalization balanced between equity and debt generally consistent with the balance of their capitalization prior to the Separation. Although the aggregate amount and particular series of preferred and debt securities of each Utility operating company to be redeemed as well as the redemption dates are uncertain at this time and are expected to remain subject to change, each Utility operating company currently anticipates that all of its outstanding preferred securities, if any, will be redeemed or otherwise retired prior to the Separation and that debt securities in the following approximate aggregate amounts will be redeemed prior to or following the Separation: $.51 billion for Entergy Arkansas, $.27 billion for Entergy Gulf States Louisiana, $.38 billion for Entergy Louisiana, $.29 billion for Entergy Mississippi, $.01 billion for Entergy New Orleans, and $.30 billion for Entergy Texas. Entergy and the Utility operating companies may, subject to certain conditions, modify or supplement the manner in which the Separation is consummated. As of December 31, 2011, net transmission plant in service, which does not include transmission-related construction work in progress or general or intangible plant, for the Utility operating companies was $.94 billion for Entergy Arkansas, $.50 billion for Entergy Gulf States Louisiana, $.71 billion for Entergy Louisiana, $.51 billion for Entergy Mississippi, $.02 billion for Entergy New Orleans, and $.62 billion for Entergy Texas. Consummation of the Separation is subject to the satisfaction of the conditions applicable to Entergy and ITC contained in the Separation Agreement and the Merger Agreement, including that the sum of the principal amount of TransCo Securities issued to Entergy and the principal amount of the bridge facility entered into by TransCo’s subsidiaries is at least $1.775 billion.

Entergy Wholesale Commodities Authorizations to Operate Its Nuclear Power Plants

The NRC operating license for Palisades expires in 2031 and for FitzPatrick expires in 2034. The NRC operating license for Vermont Yankee was to expire in March 2012. In March 2011 the NRC renewed Vermont Yankee’s operating license for an additional 20 years, as a result of which the license now expires in 2032. For additional discussion regarding the continued operation of the Vermont Yankee plant, see “Impairment of Long-Lived Assets” in Note 1 to the financial statements.

The NRC operating license for Pilgrim expires in June 2012, for Indian Point 2 expires in September 2013, and for Indian Point 3 expires in December 2015, and NRC license renewal applications are in process for these plants. Under federal law, nuclear power plants may continue to operate beyond their license expiration dates while their renewal applications are pending NRC approval. Various parties have expressed opposition to renewal of the

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licenses. With respect to the Pilgrim license renewal, the Atomic Safety and Licensing Board (ASLB) of the NRC, after issuing an order denying a new hearing request, terminated its proceeding on Pilgrim’s license renewal application. With the ASLB process concluded the proceeding, including appeals of certain ASLB decisions, is now before the NRC.

In April 2007, Entergy submitted an application to the NRC to renew the operating licenses for Indian Point 2 and 3 for an additional 20 years. The ASLB has admitted 21 contentions raised by the State of New York or other parties, which were combined into 16 discrete issues. Two of the issues have been resolved, leaving 14 issues that are currently subject to ASLB hearings. In July 2011, the ASLB granted the State of New York’s motion for summary disposition of an admitted contention challenging the adequacy of a section of Indian Point’s environmental analysis as incorporated in the FSEIS (discussed below). That section provided cost estimates for Severe Accident Mitigation Alternatives (SAMAs), which are hardware and procedural changes that could be implemented to mitigate estimated impacts of off-site radiological releases in case of a hypothesized severe accident. In addition to finding that the SAMA cost analysis was insufficient, the ASLB directed the NRC staff to explain why cost-beneficial SAMAs should not be required to be implemented. Entergy appealed the ASLB’s decision to the NRC and the NRC staff supported Entergy’s appeal, while the State of New York opposed it. In December 2011 the NRC denied Entergy’s appeal as premature, stating that the appeal could be renewed at the conclusion of the ASLB proceedings.

In November 2011 the ASLB issued an order establishing deadlines for the submission of several rounds of testimony on most of the contentions pending before the ASLB and for the filing of motions to limit or exclude testimony. Initial hearings before the ASLB on the contentions for which testimony is submitted are expected to begin by the end of 2012. Filing deadlines for testimony on certain admitted contentions remain to be set by the ASLB.

The NRC staff currently is also performing its technical and environmental reviews of the application. The NRC staff issued a Final Safety Evaluation Report (FSER) in August 2009, a supplement to the FSER in August 2011, and a Final Supplemental Environmental Impact Statement (FSEIS) in December 2010. The NRC staff has stated its intent to file a supplemental FSEIS in May 2012. The New York State Department of Environmental Conservation has taken the position that Indian Point must obtain a new state-issued Clean Water Act Section 401 water quality certification as part of the license renewal process. In addition, the consistency of Indian Point’s operations with New York State’s coastal management policies must be resolved as required by the Coastal Zone Management Act. Entergy Wholesale Commodities’ efforts to obtain these certifications and determinations continue in 2012.

The hearing process is an integral component of the NRC’s regulatory framework, and evidentiary hearings on license renewal applications are not uncommon. Entergy intends to participate fully in the hearing process as permitted by the NRC’s hearing rules. As noted in Entergy’s responses to the various intervenor filings, Entergy believes the contentions proposed by the intervenors are unsupported and without merit. Entergy will continue to work with the NRC staff as it completes its technical and environmental reviews of the license renewal application.

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Liquidity and Capital Resources

This section discusses Entergy’s capital structure, capital spending plans and other uses of capital, sources of capital, and the cash flow activity presented in the cash flow statement.

Capital Structure

Entergy’s capitalization is balanced between equity and debt, as shown in the following table.

	2011	2010

Debt to capital	57.3%	57.3%
Effect of excluding securitization bonds	(2.3)%	(2.0)%
Debt to capital, excluding securitization bonds (1)	55.0%	55.3%
Effect of subtracting cash	(1.5)%	(3.2)%
Net debt to net capital, excluding securitization bonds (1)	53.5%	52.1%

(1)	Calculation excludes the Arkansas, Louisiana, and Texas securitization bonds, which are non-recourse to Entergy Arkansas, Entergy Louisiana, and Entergy Texas, respectively.

Net debt consists of debt less cash and cash equivalents. Debt consists of notes payable, capital lease obligations, and long-term debt, including the currently maturing portion. Capital consists of debt, common shareholders’ equity, and subsidiaries’ preferred stock without sinking fund. Net capital consists of capital less cash and cash equivalents. Entergy uses the net debt to net capital ratio and the ratios excluding securitization bonds in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy’s financial condition.

Long-term debt, including the currently maturing portion, makes up substantially all of Entergy’s total debt outstanding. Following are Entergy’s long-term debt principal maturities and estimated interest payments as of December 31, 2011. To estimate future interest payments for variable rate debt, Entergy used the rate as of December 31, 2011. The amounts below include payments on the Entergy Louisiana and System Energy sale-leaseback transactions, which are included in long-term debt on the balance sheet.

Long-term debt maturities and estimated interest payments	2012	2013	2014	2015-2016	after 2016
	(In Millions)

Utility	$721	$1,197	$614	$1,524	$10,872
Entergy Wholesale Commodities	24	15	16	21	59
Parent and Other	1,972	43	43	610	535
Total	$2,717	$1,255	$673	$2,155	$11,466

Note 5 to the financial statements provides more detail concerning long-term debt outstanding.

Entergy Corporation has in place a credit facility that has a borrowing capacity of approximately $3.5 billion and expires in August 2012, which Entergy intends to renew before expiration. Because the facility is now within one year of its expiration date, borrowings outstanding on the facility are classified as currently maturing long-term debt on the balance sheet. Entergy Corporation also has the ability to issue letters of credit against the total borrowing capacity of the credit facility. The facility fee is currently 0.125% of the commitment amount. Facility fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the year ended December 31, 2011 was 0.745% on the drawn portion of the facility.

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As of December 31, 2011, amounts outstanding and capacity available under the $3.5 billion credit facility are:

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)

$3,451	$1,920	$28	$1,503

A covenant in Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio of 65% or less of its total capitalization. The calculation of this debt ratio under Entergy Corporation’s credit facility is different than the calculation of the debt to capital ratio above. Entergy is currently in compliance with the covenant. If Entergy fails to meet this ratio, or if Entergy or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.

Capital lease obligations are a minimal part of Entergy’s overall capital structure, and are discussed in Note 10 to the financial statements. Following are Entergy’s payment obligations under those leases:

	2012	2013	2014	2015-2016	after 2016
	(In Millions)

Capital lease payments	$7	$6	$5	$9	$38

Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, and Entergy Texas each had credit facilities available as of December 31, 2011 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of Dec. 31, 2011

Entergy Arkansas	April 2012	$78 million (b)	3.25%	-
Entergy Gulf States Louisiana	August 2012	$100 million (c)	0.71%	-
Entergy Louisiana	August 2012	$200 million (d)	0.67%	$50 million
Entergy Mississippi	May 2012	$35 million (e)	2.05%	-
Entergy Mississippi	May 2012	$25 million (e)	2.05%	-
Entergy Mississippi	May 2012	$10 million (e)	2.05%	-
Entergy Texas	August 2012	$100 million (f)	0.77%	-

(a)	The interest rate is the weighted average interest rate as of December 31, 2011 applied, or that would be applied, to outstanding borrowings under the facility.
(b)	The credit facility requires Entergy Arkansas to maintain a debt ratio of 65% or less of its total capitalization. Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable.
(c)	The credit facility allows Entergy Gulf States Louisiana to issue letters of credit against the borrowing capacity of the facility. As of December 31, 2011, no letters of credit were outstanding. The credit facility requires Entergy Gulf States Louisiana to maintain a consolidated debt ratio of 65% or less of its total capitalization.
(d)	The credit facility allows Entergy Louisiana to issue letters of credit against the borrowing capacity of the facility. As of December 31, 2011, no letters of credit were outstanding. The credit facility requires Entergy Louisiana to maintain a consolidated debt ratio of 65% or less of its total capitalization.
(e)	Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable. Entergy Mississippi is required to maintain a consolidated debt ratio of 65% or less of its total capitalization.

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(f)

The credit facility allows Entergy Texas to issue letters of credit against the borrowing capacity of the facility. As of December 31, 2011, no letters of credit were outstanding. The credit facility requires Entergy Texas to maintain a consolidated debt ratio of 65% or less of its total capitalization. Pursuant to the terms of the credit agreement, securitization bonds are excluded from debt and capitalization in calculating the debt ratio.

Operating Lease Obligations and Guarantees of Unconsolidated Obligations

Entergy has a minimal amount of operating lease obligations and guarantees in support of unconsolidated obligations. Entergy’s guarantees in support of unconsolidated obligations are not likely to have a material effect on Entergy’s financial condition, results of operations, or cash flows. Following are Entergy’s payment obligations as of December 31, 2011 on non-cancelable operating leases with a term over one year:

	2012	2013	2014	2015-2016	after 2016
	(In Millions)

Operating lease payments	$85	$78	$79	$100	$166

The operating leases are discussed in Note 10 to the financial statements.

Summary of Contractual Obligations of Consolidated Entities

Contractual Obligations	2012	2013-2014	2015-2016	after 2016	Total
	(In Millions)

Long-term debt (1)	$2,717	$1,928	$2,155	$11,466	$18,266
Capital lease payments (2)	$7	$11	$9	$38	$65
Operating leases (2)	$85	$157	$100	$166	$508
Purchase obligations (3)	$1,803	$2,604	$1,654	$5,199	$11,260

(1)	Includes estimated interest payments. Long-term debt is discussed in Note 5 to the financial statements.
(2)	Lease obligations are discussed in Note 10 to the financial statements.
(3)	Purchase obligations represent the minimum purchase obligation or cancellation charge for contractual obligations to purchase goods or services. Almost all of the total are fuel and purchased power obligations.

In addition to the contractual obligations, Entergy currently expects to contribute approximately $162.9 million to its pension plans and approximately $80.4 million to other postretirement plans in 2012, although the required pension contributions will not be known with more certainty until the January 1, 2012 valuations are completed by April 1, 2012. Entergy’s preliminary estimates of 2012 funding requirements indicate that the contributions will not exceed historical levels of pension contributions.

Also in addition to the contractual obligations, Entergy has $812 million of unrecognized tax benefits and interest net of unused tax attributes for which the timing of payments beyond 12 months cannot be reasonably estimated due to uncertainties in the timing of effective settlement of tax positions. See Note 3 to the financial statements for additional information regarding unrecognized tax benefits.

Capital Funds Agreement

Pursuant to an agreement with certain creditors, Entergy Corporation has agreed to supply System Energy with sufficient capital to:

·	maintain System Energy’s equity capital at a minimum of 35% of its total capitalization (excluding short-term debt);

·	permit the continued commercial operation of Grand Gulf;

·	pay in full all System Energy indebtedness for borrowed money when due; and

·	enable System Energy to make payments on specific System Energy debt, under supplements to the agreement assigning System Energy’s rights in the agreement as security for the specific debt.

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Capital Expenditure Plans and Other Uses of Capital

Following are the amounts of Entergy’s planned construction and other capital investments by operating segment for 2012 through 2014:

Planned construction and capital investments		2012	2013	2014
		(In Millions)

Maintenance Capital:
	Utility:
	Generation	$128	$129	$131
	Transmission	282	273	255
	Distribution	433	485	496
	Other	91	89	103
	Total	934	976	985
	Entergy Wholesale Commodities	90	120	107
		1,024	1,096	1,092
Capital Commitments:
	Utility:
	Generation	$1,428	$583	$358
	Transmission	170	128	264
	Distribution	17	11	11
	Other	45	47	35
	Total	1,660	769	668
	Entergy Wholesale Commodities	259	241	291
		1,919	1,010	959
Total		$2,943	$2,106	$2,051

Maintenance Capital refers to amounts Entergy plans to spend on routine capital projects that are necessary to support reliability of its service, equipment, or systems and to support normal customer growth.

Capital Commitments refers to non-routine capital investments for which Entergy is either contractually obligated, has Board approval, or otherwise expects to make to satisfy regulatory or legal requirements. Amounts reflected in this category include the following:

·	The currently planned construction or purchase of additional generation supply sources within the Utility’s service territory through the Utility’s portfolio transformation strategy, including three resources identified in the Summer 2009 Request for Proposal that are discussed below.

·	Entergy Louisiana’s Waterford 3 steam generators replacement project, which is discussed below.

System Energy’s planned approximate 178 MW uprate of the Grand Gulf nuclear plant. On November 30, 2009, the MPSC issued a Certificate of Public Convenience and Necessity for implementation of the uprate. A license amendment application was submitted to the NRC in September 2010. After performing more detailed project design, engineering, analysis and major materials purchases, System Energy’s current estimate of the total capital investment to be made in the course of the implementation of the Grand Gulf uprate project is approximately $754 million, including SMEPA’s share. The estimate includes spending on certain major equipment refurbishment and replacement that would have been required over the normal course of the plant’s life even if the uprate were not done. The purpose of performing this major equipment refurbishment and replacement in connection with the uprate is to avoid additional plant outages and construction costs in the future while improving plant reliability. The investment estimate may be revised in the future as System Energy evaluates the progress of the project, including the costs required to install instrumentation in the steam dryer in response to recent guidance from the NRC staff obtained during the review process for certain Requests for Additional Information (RAIs) issued by the NRC in December 2011. The NRC’s review of the project is ongoing. System Energy is responding to the recent RAIs and will seek to minimize potential cost effects or delay, if any, to the Grand Gulf uprate implementation schedule.

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·	Transmission upgrades and spending to support the Utility’s plan to join the MISO RTO by December 2013.

·	Spending to comply with current and anticipated North American Electric Reliability Corporation transmission planning requirements.

·	Entergy Wholesale Commodities investments associated with specific investments such as dry cask storage, nuclear license renewal, component replacement and identified repairs, spending in response to the Indian Point Safety Evaluation, NYPA value sharing, and wedgewire screens at Indian Point.

A minimal amount of environmental compliance spending, although Entergy continues to review potential environmental spending needs and financing alternatives for any such spending, and future spending estimates could change based on the results of this continuing analysis and the implementation of new environmental laws and regulations.

The Utility’s owned generating capacity remains short of customer demand, and its supply plan initiative will continue to seek to transform its generation portfolio with new or repowered generation resources. Opportunities resulting from the supply plan initiative, including new projects or the exploration of alternative financing sources, could result in increases or decreases in the capital expenditure estimates given above. Estimated capital expenditures are also subject to periodic review and modification and may vary based on the ongoing effects of business restructuring, regulatory constraints and requirements, environmental regulations, business opportunities, market volatility, economic trends, changes in project plans, and the ability to access capital.

Summer 2009 Long-Term Request for Proposal

The 2012-2014 capital expenditure estimate includes the construction or purchase of three resources identified in the Summer 2009 Long-Term Request for Proposal: a self-build option at Entergy Louisiana’s Ninemile site and agreements by two of the Utility operating companies to acquire the 620 MW Hot Spring Energy Facility and the 450 MW Hinds Energy Facility.

Ninemile Point Unit 6 Self-Build Project

In June 2011, Entergy Louisiana filed with the LPSC an application seeking certification that the public necessity and convenience would be served by Entergy Louisiana’s construction of a combined-cycle gas turbine generating facility (Ninemile 6) at its existing Ninemile Point electric generating station. Ninemile 6 will be a nominally-sized 550 MW unit that is estimated to cost approximately $721 million to construct, excluding interconnection and transmission upgrades. Entergy Gulf States Louisiana joined in the application, seeking certification of its purchase under a life-of-unit power purchase agreement of up to 35% of the capacity and energy generated by Ninemile 6. The Ninemile 6 capacity and energy is proposed to be allocated 55% to Entergy Louisiana, 25% to Entergy Gulf States Louisiana, and 20% to Entergy New Orleans. In February 2012 the City Council passed a resolution authorizing Entergy New Orleans to purchase 20% of the Ninemile 6 energy and capacity. If approvals are obtained from the LPSC and other permitting agencies, Ninemile 6 construction is expected to begin in 2012, and the unit is expected to commence commercial operation by mid-2015. The ALJ has established a schedule for the LPSC proceeding that includes February 27 - March 7, 2012, hearing dates.

Hot Spring Energy Facility Purchase Agreement

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supplemental upgrades in the Entergy transmission system are needed to make energy from the Hot Spring Energy Facility deliverable to Entergy Arkansas for the period after Entergy Arkansas exits the System Agreement. The initial results of the service request were received in January 2012 and indicate that available transfer capability does not exist with existing transmission facilities and that upgrades are required. The studies do not provide a final and definitive indication of what those upgrades would be. Entergy Arkansas has submitted transmission service requests for facilities studies which, when performed by the ICT, will provide more detailed estimates of the transmission upgrades and the associated costs required to obtain network service for the Hot Spring plant. Accordingly there are still uncertainties that must be resolved. The purchase is contingent upon, among other things, obtaining necessary approvals, including full cost recovery, from various federal and state regulatory and permitting agencies. These include regulatory approvals from the APSC and the FERC, as well as clearance under the Hart-Scott-Rodino anti-trust law. In February 2012 the FERC issued an order approving the acquisition. Closing is expected to occur in mid-2012.

In July 2011, Entergy Arkansas filed its application with the APSC requesting approval of the acquisition and full cost recovery. In January 2012, Entergy Arkansas, the APSC General Staff, and the Arkansas Attorney General filed a Motion to Suspend the Procedural Schedule and Joint Stipulation and Settlement for consideration by the APSC. Under the settlement, the parties agreed that the acquisition costs may be recovered through a capacity acquisition rider and agreed that the level of the return on equity reflected in the rider would be submitted to the APSC for resolution. Because the transmission upgrade costs remain uncertain, the parties requested that the APSC suspend the procedural schedule and cancel the hearing scheduled for January 24, 2012, pending resolution of the transmission costs. The APSC issued an order accepting the settlement as part of the record and directing Entergy Arkansas to file the transmission studies when available and directing the parties to propose a procedural schedule to address the results of those studies.

Hinds Energy Facility Purchase Agreement

In April 2011, Entergy Mississippi announced that it has signed an asset purchase agreement to acquire the Hinds Energy Facility, a 450 MW natural gas-fired combined-cycle turbine plant located in Jackson, Mississippi, from a subsidiary of KGen Power Corporation. The purchase price is expected to be approximately $206 million. Entergy Mississippi also expects to invest in various plant upgrades at the facility after closing and expects the total cost of the acquisition to be approximately $246 million. A new transmission service request has been submitted to determine if investments for supplemental upgrades in the Entergy transmission system are needed to make the Hinds Energy Facility deliverable to Entergy Mississippi for the period after Entergy Mississippi exits the System Agreement. Facilities studies are ongoing to determine transmission upgrades costs associated with the plant, with results expected by early March 2012. The purchase is contingent upon, among other things, obtaining necessary approvals, including full cost recovery, from various federal and state regulatory and permitting agencies. These include regulatory approvals from the MPSC and the FERC, as well as clearance under the Hart-Scott-Rodino anti-trust law. In February 2012 the FERC issued an order approving the acquisition. Closing is expected to occur in mid-2012. In July 2011, Entergy Mississippi filed with the MPSC requesting approval of the acquisition and full cost recovery. A hearing on the request for a certificate of public convenience and necessity is scheduled for February 28, 2012. A hearing on Entergy Mississippi’s proposed cost recovery has not been scheduled.

Waterford 3 Steam Generator Replacement Project

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replacement steam generators (RSGs), in areas beneath and adjacent to the divider plate. As a result of this damage, the manufacturer was unable to meet the contractual delivery deadlines, and the RSGs were not installed in the spring 2011. Entergy Louisiana worked with the manufacturer to fully develop and evaluate repair options, and expects the replacement steam generators to be delivered in time for the Fall 2012 refueling outage. Extensive inspections of the existing steam generators at Waterford 3 in cooperation with the manufacturer were completed in April 2011. The review of data obtained during these inspections supports the conclusion that Waterford 3 can operate safely for another full cycle before the replacement of the existing steam generators. Entergy Louisiana has formally reported its findings to the NRC. At this time, a requirement to perform a mid-cycle outage for further inspections in order to allow the plant to continue operation until its Fall 2012 refueling outage is not anticipated. Entergy Louisiana currently expects the cost of the project, including carrying costs, to be approximately $687 million, assuming the replacement occurs during the Fall 2012 refueling outage.

In June 2008, Entergy Louisiana filed with the LPSC for approval of the replacement project, including full cost recovery. Following discovery and the filing of testimony by the LPSC staff and an intervenor, the parties entered into a stipulated settlement of the proceeding. The LPSC unanimously approved the settlement in November 2008. The settlement resolved the following issues: 1) the accelerated degradation of the steam generators is not the result of any imprudence on the part of Entergy Louisiana; 2) the decision to undertake the replacement project at the then-estimated cost of $511 million is in the public interest, is prudent, and would serve the public convenience and necessity; 3) the scope of the replacement project is in the public interest; 4) undertaking the replacement project at the target installation date during the 2011 refueling outage is in the public interest; and 5) the jurisdictional costs determined to be prudent in a future prudence review are eligible for cost recovery, either in an extension or renewal of the formula rate plan or in a full base rate case including necessary pro forma adjustments. Upon completion of the replacement project, the LPSC will undertake a prudence review with regard to the following aspects of the replacement project: 1) project management; 2) cost controls; 3) success in achieving stated objectives; 4) the costs of the replacement project; and 5) the outage length and replacement power costs.

In November 2011 the LPSC approved a one-year extension of Entergy Louisiana’s current formula rate plan. The next formula rate plan filing, for the 2011 test year, will be made in May 2012 and will include a separate identification of any operating and maintenance expense savings that are expected to occur once the Waterford 3 steam generator replacement project is complete. Pursuant to the LPSC decision, from September 2012 through December 2012 earnings above an 11.05% return on common equity (based on the 2011 test year) would be accrued and used to offset the Waterford 3 replacement steam generator revenue requirement for the first twelve months that the unit is in rates. If the project is not in service by January 1, 2013, earnings above a 10.25% return on common equity (based on the 2011 test year) for the period January 1, 2013 through the date that the project is placed in service will be accrued and used to offset the incremental revenue requirement for the first twelve months that the unit is in rates. Upon the in-service date of the replacement steam generators, rates will increase, subject to refund following any prudence review, by the full revenue requirement associated with the replacement steam generators, less (i) the previously accrued excess earnings from September 2012 until the in-service date and (ii) any earnings above a 10.25% return on common equity (based on the 2011 test year) for the period following the in-service date, provided that the excess earnings accrued prior to the in-service date shall only offset the revenue requirement for the first year of operation of the replacement steam generators. These rates are anticipated to remain in effect until Entergy Louisiana’s next full rate case is resolved. Entergy Louisiana currently anticipates filing a full rate case by January 2013.

Dividends and Stock Repurchases

Declarations of dividends on Entergy’s common stock are made at the discretion of the Board. Among other things, the Board evaluates the level of Entergy’s common stock dividends based upon Entergy’s earnings, financial strength, and future investment opportunities. At its January 2012 meeting, the Board declared a dividend of $0.83 per share, which is the same quarterly dividend per share that Entergy has paid since the second quarter 2010. The prior quarterly dividend per share was $0.75. Entergy paid $590 million in 2011, $604 million in 2010, and $577 million in 2009 in cash dividends on its common stock.

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In accordance with Entergy’s stock-based compensation plan, Entergy periodically grants stock options to key employees, which may be exercised to obtain shares of Entergy’s common stock. According to the plan, these shares can be newly issued shares, treasury stock, or shares purchased on the open market. Entergy’s management has been authorized by the Board to repurchase on the open market shares up to an amount sufficient to fund the exercise of grants under the plan.

In addition to the authority to fund grant exercises, in January 2007 the Board approved a program under which Entergy was authorized to repurchase up to $1.5 billion of its common stock. In January 2008, the Board authorized an incremental $500 million share repurchase program to enable Entergy to consider opportunistic purchases in response to equity market conditions. Entergy completed both the $1.5 billion and $500 million programs in the third quarter 2009. In October 2009 the Board granted authority for an additional $750 million share repurchase program which was completed in the fourth quarter 2010. In October 2010 the Board granted authority for an additional $500 million share repurchase program. As of December 31, 2011, $350 million of authority remains under the $500 million share repurchase program. The amount of repurchases may vary as a result of material changes in business results or capital spending or new investment opportunities, or if limitations in the credit markets continue for a prolonged period.

Sources of Capital

Entergy’s sources to meet its capital requirements and to fund potential investments include:

·	internally generated funds;

·	cash on hand ($694 million as of December 31, 2011);

·	securities issuances;

·	bank financing under new or existing facilities; and

·	sales of assets.

Circumstances such as weather patterns, fuel and purchased power price fluctuations, and unanticipated expenses, including unscheduled plant outages and storms, could affect the timing and level of internally generated funds in the future.

Provisions within the Articles of Incorporation or pertinent indentures and various other agreements relating to the long-term debt and preferred stock of certain of Entergy Corporation’s subsidiaries could restrict the payment of cash dividends or other distributions on their common and preferred stock. As of December 31, 2011, under provisions in their mortgage indentures, Entergy Arkansas and Entergy Mississippi had restricted retained earnings unavailable for distribution to Entergy Corporation of $394.9 million and $68.5 million, respectively. All debt and common and preferred equity issuances by the Registrant Subsidiaries require prior regulatory approval and their preferred equity and debt issuances are also subject to issuance tests set forth in corporate charters, bond indentures, and other agreements. Entergy believes that the Registrant Subsidiaries have sufficient capacity under these tests to meet foreseeable capital needs.

The FERC has jurisdiction over securities issuances by the Utility operating companies and System Energy (except securities with maturities longer than one year issued by Entergy Arkansas and Entergy New Orleans, which are subject to the jurisdiction of the APSC and the City Council, respectively). No regulatory approvals are necessary for Entergy Corporation to issue securities. The current FERC-authorized short-term borrowing limits are effective through October 31, 2013. Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through July 2013. Entergy Arkansas has obtained long-term financing authorization from the APSC that extends through December 2012. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through July 2012. In addition to borrowings from commercial banks, the FERC short-term borrowing orders authorize the Registrant Subsidiaries to continue as participants in the Entergy System money pool. The money pool is an

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intercompany borrowing arrangement designed to reduce Entergy’s subsidiaries’ dependence on external short-term borrowings. Borrowings from the money pool and external short-term borrowings combined may not exceed the FERC-authorized limits. See Notes 4 and 5 to the financial statements for further discussion of Entergy’s borrowing limits, authorizations, and amounts outstanding.

In January 2012, Entergy Corporation issued $500 million of 4.70% senior notes due January 2017. Entergy Corporation used the proceeds to repay borrowings under its $3.5 billion credit facility.

In January 2012, Entergy Louisiana issued $250 million of 1.875% Series first mortgage bonds due December 2014. Entergy Louisiana used the proceeds to repay short-term borrowings under the Entergy System money pool.

Hurricane Gustav and Hurricane Ike

In September 2008, Hurricane Gustav and Hurricane Ike caused catastrophic damage to portions of Entergy's service territories in Louisiana and Texas, and to a lesser extent in Arkansas and Mississippi. The storms resulted in widespread power outages, significant damage to distribution, transmission, and generation infrastructure, and the loss of sales during the power outages. In September 2009, Entergy Gulf States Louisiana and Entergy Louisiana and the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, filed with the LPSC an application requesting that the LPSC grant financing orders authorizing the financing of Entergy Gulf States Louisiana’s and Entergy Louisiana’s storm costs, storm reserves, and issuance costs pursuant to Act 55 of the Louisiana Regular Session of 2007 (Act 55 financings). In July 2010 the Louisiana Local Government Environmental Facilities and Community Development Authority (LCDA) issued $468.9 million in bonds under Act 55. From the $462.4 million of bond proceeds loaned by the LCDA to the LURC, the LURC deposited $200 million in a restricted escrow account as a storm damage reserve for Entergy Louisiana and transferred $262.4 million directly to Entergy Louisiana. In July 2010 the LCDA issued another $244.1 million in bonds under Act 55. From the $240.3 million of bond proceeds loaned by the LCDA to the LURC, the LURC deposited $90 million in a restricted escrow account as a storm damage reserve for Entergy Gulf States Louisiana and transferred $150.3 million directly to Entergy Gulf States Louisiana. Entergy, Entergy Gulf States Louisiana, and Entergy Louisiana do not report the bonds on their balance sheets because the bonds are the obligation of the LCDA, and there is no recourse against Entergy, Entergy Gulf States Louisiana or Entergy Louisiana in the event of a bond default. See Note 2 to the financial statements for additional discussion of the Act 55 financings.

In November 2009, Entergy Texas Restoration Funding, LLC (Entergy Texas Restoration Funding), a company wholly-owned and consolidated by Entergy Texas, issued $545.9 million of senior secured transition bonds (securitization bonds) to finance Entergy Texas Hurricane Ike and Hurricane Gustav restoration costs. See Note 2 to the financial statements for a discussion of the proceeding approving the issuance of the securitization bonds and see Note 5 to the financial statements for a discussion of the terms of the securitization bonds.

In the third quarter 2009, Entergy settled with its insurer on its Hurricane Ike claim and Entergy Texas received $75.5 million in proceeds (Entergy received a total of $76.5 million).

Entergy Arkansas January 2009 Ice Storm

In January 2009, a severe ice storm caused significant damage to Entergy Arkansas’s transmission and distribution lines, equipment, poles, and other facilities. A law was enacted in April 2009 in Arkansas that authorizes securitization of storm damage restoration costs. In June 2010, the APSC issued a financing order authorizing the issuance of storm cost recovery bonds, including carrying costs of $11.5 million and $4.6 million of up-front financing costs. In August 2010, Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, issued $124.1 million of storm cost recovery bonds. See Note 5 to the financial statements for additional discussion of the issuance of the storm cost recovery bonds.

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Entergy Louisiana Securitization Bonds – Little Gypsy

Cash Flow Activity

As shown in Entergy’s Statements of Cash Flows, cash flows for the years ended December 31, 2011, 2010, and 2009 were as follows:

		2011	2010	2009
		(In Millions)

Cash and cash equivalents at beginning of period		$1,295	$1,710	$1,920

Cash flow provided by (used in):
	Operating activities	3,128	3,926	2,933
	Investing activities	(3,447)	(2,574)	(2,094)
	Financing activities	(282)	(1,767)	(1,048)
Effect of exchange rates on cash and cash equivalents		-	-	(1)
	Net decrease in cash and cash equivalents	(601)	(415)	(210)

Cash and cash equivalents at end of period		$694	$1,295	$1,710

Operating Cash Flow Activity

2011 Compared to 2010

Entergy's cash flow provided by operating activities decreased by $797 million in 2011 compared to 2010 primarily due to the receipt in July 2010 of $703 million from the Louisiana Utilities Restoration Corporation as a result of the Louisiana Act 55 storm cost financings for Hurricane Gustav and Hurricane Ike. The Act 55 storm cost financings are discussed in Note 2 to the financial statements. The decrease in Entergy Wholesale Commodities net revenue that is discussed above also contributed to the decrease in operating cash flow.

2010 Compared to 2009

Entergy’s cash flow provided by operating activities increased $993 million in 2010 compared to 2009 primarily due to the receipt in July 2010 of $703 million from the Louisiana Utilities Restoration Corporation as a result of the Louisiana Act 55 storm cost financings, as noted in the preceding paragraph. In addition, the absence of the Hurricane Gustav, Hurricane Ike, and Arkansas ice storm restoration spending that occurred in 2009 also contributed to the increase. These factors were partially offset by an increase of $323 million in pension contributions at Utility and Entergy Wholesale Commodities and a decrease in net revenue at Entergy Wholesale Commodities. See “Critical Accounting Estimates - Qualified Pension and Other Postretirement Benefits” below and also Note 11 to the financial statements for further discussion of pension funding.

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Investing Activities

2011 Compared to 2010

Net cash used in investing activities increased $873 million in 2011 compared to 2010 primarily due to the following activity:

the purchase of the Acadia Power Plant by Entergy Louisiana for approximately $300 million in April 2011, the purchase of the Rhode Island State Energy Center for approximately $346 million by an Entergy Wholesale Commodities subsidiary in December 2011, and the sale of an Entergy Wholesale Commodities subsidiary’s ownership interest in the Harrison County Power Project for proceeds of $219 million in 2010. These transactions are described in more detail in Note 15 to the financial statements;

·	an increase in nuclear fuel purchases because of variations from year to year in the timing and pricing of fuel reload requirements, material and services deliveries, and the timing of cash payments during the nuclear fuel cycle; and

a slight increase in construction expenditures, including spending resulting from April 2011 storms that caused damage to transmission and distribution lines, equipment, poles, and other facilities, primarily in Arkansas. The capital cost of repairing that damage was approximately $55 million. Entergy’s construction spending plans for 2012 through 2014 are discussed in “Management’s Financial Discussion and Analysis - Capital Expenditure Plans and Other Uses of Capital.”

These increases were offset by the investment in 2010 of a total of $290 million in Entergy Gulf States Louisiana’s and Entergy Louisiana’s storm reserve escrow accounts as a result of their Act 55 storm cost financings, which are discussed in Note 2 to the financial statements.

2010 Compared to 2009

Net cash used in investing activities increased $480 million in 2010 compared to 2009 primarily due to the following activity:

an increase in net uses of cash for nuclear fuel purchases, which was caused by the consolidation of the nuclear fuel company variable interest entities that is discussed in Note 18 to the financial statements. With the consolidation of the nuclear fuel company variable interest entities, their purchases of nuclear fuel from Entergy are now eliminated in consolidation, whereas before 2010 they were a source of investing cash flows;

·	the investment of a total of $290 million in Entergy Gulf States Louisiana’s and Entergy Louisiana’s storm reserve escrow accounts as a result of their Act 55 storm cost financings, which are discussed in Note 2 to the financial statements;

·	an increase in construction expenditures, primarily in the Entergy Wholesale Commodities business, as decreases for the Utility resulting from Hurricane Gustav, Hurricane Ike, and Arkansas ice storm restoration spending in 2009 were offset by spending on various projects; and

·	the sale of an Entergy Wholesale Commodities subsidiary’s ownership interest in the Harrison County Power Project for proceeds of $219 million in 2010. The sale is described in more detail in Note 15 to the financial statements.

Financing Activities

2011 Compared to 2010

Net cash used in financing activities decreased $1,485 million in 2011 compared to 2010 primarily because long-term debt activity provided approximately $554 million of cash in 2011 and used approximately $307 million of cash in 2010. The most significant long-term debt activity in 2011 included the issuance of $207 million of securitization bonds by a subsidiary of Entergy Louisiana, the issuance of $200 million of first mortgage bonds by Entergy

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Louisiana, and Entergy Corporation increasing the borrowings outstanding on its 5-year credit facility by $288 million. For the details of Entergy’s long-term debt outstanding on December 31, 2011 and 2010 see Note 5 to the financial statements herein. In addition to the long-term debt activity, Entergy Corporation repurchased $236 million of its common stock in 2011 and repurchased $879 million of its common stock in 2010. Entergy’s stock repurchases are discussed further in the “Capital Expenditure Plans and Other Uses of Capital - Dividends and Stock Repurchases” section above.

2010 Compared to 2009

Net cash used in financing activities increased $719 million in 2010 compared to 2009 primarily because long-term debt activity used approximately $307 million of cash in 2010 and provided approximately $160 million of cash in 2009. The most significant net use for long-term debt activity was by Entergy Corporation, which reduced its 5-year credit facility balance by $934 million and repaid a total of $275 million of notes and bank term loans, while issuing $1 billion of notes in 2010. For the details of Entergy’s long-term debt outstanding see Note 5 to the financial statements herein. In addition, Entergy Corporation repurchased $879 million of its common stock in 2010 and repurchased $613 million of its common stock in 2009. Entergy’s stock repurchases are discussed further in the “Capital Expenditure Plans and Other Uses of Capital - Dividends and Stock Repurchases” section above.

Rate, Cost-recovery, and Other Regulation

State and Local Rate Regulation and Fuel-Cost Recovery

The rates that the Utility operating companies and System Energy charge for their services significantly influence Entergy’s financial position, results of operations, and liquidity. These companies are regulated and the rates charged to their customers are determined in regulatory proceedings. Governmental agencies, including the APSC, the City Council, the LPSC, the MPSC, the PUCT, and the FERC, are primarily responsible for approval of the rates charged to customers. Following is a summary of the Utility operating companies’ authorized returns on common equity and current retail base rates. The Utility operating companies’ base rate, fuel and purchased power cost recovery, and storm cost recovery proceedings are discussed in Note 2 to the financial statements.

Company	Authorized Return on Common Equity

Entergy Arkansas	10.2%	- Current retail base rates implemented in the July 2010 billing cycle pursuant to a settlement approved by the APSC.

Entergy Gulf States Louisiana	9.9%-11.4% Electric; 10.0%-11.0% Gas	- Current retail electric base rates implemented based on Entergy Gulf States Louisiana's 2010 test year formula rate plan filing approved by the LPSC. - Current retail gas base rates reflect the rate stabilization plan filing for the 2010 test year ended September 2010.

Entergy Louisiana	9.45%- 11.05%	- Current retail base rates based on Entergy Louisiana's 2010 test year formula rate plan filing approved by the LPSC.

Entergy Mississippi	10.54%- 12.72%	- Current retail base rates reflect Entergy Mississippi's latest formula rate plan filing, based on the 2010 test year, and a stipulation approved by the MPSC.

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Company	Authorized Return on Common Equity
Entergy New Orleans	10.7% - 11.5% Electric; 10.25% - 11.25% Gas	- Current retail base rates reflect Entergy New Orleans's 2010 test year formula rate plan filing and a settlement approved by the City Council.

Entergy Texas	10.125%	- Current retail base rates reflect Entergy Texas's 2009 base rate case filing and a settlement approved by the PUCT.

Federal Regulation

Independent Coordinator of Transmission

In 2000, the FERC issued an order encouraging utilities to voluntarily place their transmission facilities under the control of independent RTOs (regional transmission organizations). Delays in implementing the FERC RTO order occurred due to a variety of reasons, including the fact that utility companies, other stakeholders, and federal and state regulators have had to work to resolve various issues related to the establishment of such RTOs. In November 2006, the Utility operating companies installed the Southwest Power Pool (SPP), a regional transmission organization, as their Independent Coordinator of Transmission (ICT). The installation does not transfer control of Entergy’s transmission system to the ICT, but rather vests with the ICT responsibility for:

·	granting or denying transmission service on the Utility operating companies’ transmission system.

·	administering the Utility operating companies’ OASIS node for purposes of processing and evaluating transmission service requests and ensuring compliance with the Utility operating companies’ obligation to post transmission-related information.

developing a base plan for the Utility operating companies’ transmission system that will result in the ICT making the determination on whether costs of transmission upgrades should be rolled into the Utility operating companies’ transmission rates or directly assigned to the customer requesting or causing an upgrade to be constructed. This should result in a transmission pricing structure that ensures that the Utility operating companies’ retail native load customers are required to pay for only those upgrades necessary to reliably and economically serve their needs.

·	serving as the reliability coordinator for the Entergy transmission system.

·	overseeing the operation of the weekly procurement process (WPP).

evaluating interconnection-related investments already made on the Entergy System for purposes of determining the future allocation of the uncredited portion of these investments, pursuant to a detailed methodology. The ICT agreement also clarifies the rights that customers receive when they fund a supplemental upgrade.

The FERC, in conjunction with the APSC, the LPSC, the MPSC, the PUCT, and the City Council, hosted a conference on June 24, 2009, to discuss the ICT arrangement and transmission access on the Entergy transmission system. During the conference, several issues were raised by regulators and market participants, including the adequacy of the Utility operating companies’ capital investment in the transmission system, the Utility operating companies’ compliance with the existing North American Electric Reliability Corporation (NERC) reliability planning standards, the availability of transmission service across the system, and whether the Utility operating companies could have purchased lower cost power from merchant generators located on the transmission system rather than running their older generating facilities. On July 20, 2009, the Utility operating companies filed comments with the FERC responding to the issues raised during the conference. The comments explain that: 1) the Utility operating companies believe that the ICT arrangement has fulfilled its objectives; 2) the Utility operating companies’ transmission

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planning practices comply with laws and regulations regarding the planning and operation of the transmission system; and 3) these planning practices have resulted in a system that meets applicable reliability standards and is sufficiently robust to allow the Utility operating companies both to substantially increase the amount of transmission service available to third parties and to make significant amounts of economic purchases from the wholesale market for the benefit of the Utility operating companies’ retail customers. The Utility operating companies also explain that, as with other transmission systems, there are certain times during which congestion occurs on the Utility operating companies’ transmission system that limits the ability of the Utility operating companies as well as other parties to fully utilize the generating resources that have been granted transmission service. Additionally, the Utility operating companies commit in their response to exploring and working on potential reforms or alternatives for the ICT arrangement that could take effect following the initial term. The Utility operating companies’ comments also recognize that NERC is in the process of amending certain of its transmission reliability planning standards and that the amended standards, if approved by the FERC, will result in more stringent transmission planning criteria being applicable in the future. The FERC may also make other changes to transmission reliability standards. These changes to the reliability standards would result in increased capital expenditures by the Utility operating companies.

The Entergy Regional State Committee (E-RSC), which is comprised of representatives from all of the Utility operating companies' retail regulators, has been formed to consider several of these issues related to Entergy's transmission system. Among other things, the E-RSC in concert with the FERC conducted a cost/benefit analysis comparing the ICT arrangement to other transmission proposals, including participation in a regional transmission organization.

In September 2010, as modified in October 2010, the Utility operating companies filed a request for a two-year interim extension, with certain modifications, of the ICT arrangement, which was scheduled to expire on November 17, 2010. In November 2010 the FERC issued an order accepting the Utility operating companies’ proposal to extend the ICT arrangement with SPP by an additional term of two years, providing time for analysis of longer term structures. In addition, in December 2010 the FERC issued an order that granted the E-RSC additional authority over transmission upgrades and cost allocation.

System Agreement

The FERC regulates wholesale rates (including Entergy Utility intrasystem energy allocations pursuant to the System Agreement) and interstate transmission of electricity, as well as rates for System Energy’s sales of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans pursuant to the Unit Power Sales Agreement. The Utility operating companies historically have engaged in the coordinated planning, construction, and operation of generating and bulk transmission facilities under the terms of the System Agreement, which is a rate schedule that has been approved by the FERC. Certain of the Utility operating companies’ retail regulators and other parties are pursuing litigation involving the System Agreement at the FERC. The proceedings include challenges to the allocation of costs as defined by the System Agreement and allegations of imprudence by the Utility operating companies in their execution of their obligations under the System Agreement. See Note 2 to the financial statements for discussions of this litigation.

Entergy Arkansas and Entergy Mississippi Notices of Termination of System Agreement Participation

In October 2007 the MPSC issued a letter confirming its belief that Entergy Mississippi should exit the System Agreement in light of the recent developments involving the System Agreement. In November 2007, Entergy Mississippi provided its written notice to terminate its participation in the System Agreement effective ninety-six (96) months from the date of the notice or such earlier date as authorized by the FERC.

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On February 2, 2009, Entergy Arkansas and Entergy Mississippi filed with the FERC their notices of cancellation to terminate their participation in the Entergy System Agreement, effective December 18, 2013 and November 7, 2015, respectively. While the FERC had indicated previously that the notices should be filed 18 months prior to Entergy Arkansas’s termination (approximately mid-2012), the filing explains that resolving this issue now, rather than later, is important to ensure that informed long-term resource planning decisions can be made during the years leading up to Entergy Arkansas’s withdrawal and that all of the Utility operating companies are properly positioned to continue to operate reliably following Entergy Arkansas’s and, eventually, Entergy Mississippi’s, departure from the System Agreement.

In November 2009 the FERC accepted the notices of cancellation and determined that Entergy Arkansas and Entergy Mississippi are permitted to withdraw from the System Agreement following the 96 month notice period without payment of a fee or the requirement to otherwise compensate the remaining Utility operating companies as a result of withdrawal. In February 2011 the FERC denied the LPSC’s and the City Council’s rehearing requests. The LPSC has appealed the FERC’s decision to the U.S. Court of Appeals for the District of Columbia and oral argument was held January 13, 2012.

Arkansas Public Service Commission System Agreement Investigation

The APSC had previously commenced an investigation, in 2004, into whether Entergy Arkansas’s continued participation in the System Agreement is in the best interests of its customers. In February 2010 the APSC issued a show cause order opening an investigation regarding the prudence of Entergy Arkansas’s entering a successor pooling agreement with the other Entergy Utility operating companies, as opposed to becoming a standalone entity upon exit from the System Agreement in December 2013, and whether Entergy Arkansas, as a standalone utility, should join the SPP RTO. The APSC subsequently added evaluation of Entergy Arkansas joining the Midwest Independent Transmission System Operator (MISO) RTO on a standalone basis as an alternative to be considered. In August 2010, the APSC directed Entergy Arkansas and all parties to compare five strategic options at the same time as follows: (1) Entergy Arkansas Self-Provide; (2) Entergy Arkansas with 3rd party coordination agreements; (3) Successor Arrangements; (4) Entergy Arkansas as a standalone member of SPP RTO; and (5) Entergy Arkansas as a standalone member of the MISO RTO.

LPSC and City Council Action Related to the Entergy Arkansas and Entergy Mississippi Notices of Termination

In light of the notices of Entergy Arkansas and Entergy Mississippi to terminate participation in the current System Agreement, in January 2008 the LPSC unanimously voted to direct the LPSC Staff to begin evaluating the potential for a successor arrangement. The New Orleans City Council opened a docket to gather information on progress towards a successor arrangement. The LPSC subsequently passed a resolution stating that it cannot evaluate successor arrangements without having certainty about System Agreement exit obligations.

Entergy’s Proposal to Join the MISO RTO

On April 25, 2011, Entergy announced that each of the Utility operating companies propose joining the MISO RTO, which is expected to provide long-term benefits for the customers of each of the Utility operating companies. MISO is a regional transmission organization that operates in 12 U.S. states (Illinois, Indiana, Iowa, Kentucky, Michigan, Minnesota, Missouri, Montana, North Dakota, Ohio, South Dakota, and Wisconsin) and also in Canada. The Utility operating companies provided analysis in May 2011 to their retail regulators supporting this decision. The APSC received additional information from Entergy, MISO, and other parties and held an evidentiary hearing in September 2011. The APSC issued an order in the proceeding in October 2011 finding that it is prudent for Entergy Arkansas to join an RTO but deferred a decision on Entergy Arkansas’s plan to join the MISO RTO until Entergy Arkansas files an application to transfer control of its transmission assets to the MISO RTO.

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Entergy’s May 2011 filings estimate that the transition and implementation costs of joining the MISO RTO could be up to $105 million if all of the Utility operating companies join the MISO RTO, most of which will be spent in late 2012 and 2013. Maintaining the viability of the alternatives of Entergy Arkansas joining the MISO RTO alone or standing alone within an ICT arrangement is expected to result in an additional cost of approximately $35 million, for a total estimated cost of up to $140 million. This amount could increase with extended litigation in various regulatory proceedings. It is expected that costs will be incurred to obtain regulatory approvals, to revise or implement commercial and legal agreements, to integrate transmission and generation facilities, to develop back-office accounting and settlement systems, and to build out communications infrastructure.

In the fourth quarter 2011, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans filed applications with their local regulators concerning their proposal to join the MISO RTO and transfer control of each company’s transmission assets to the MISO RTO. Entergy Texas expects to submit its filing in 2012. The applications to join the MISO RTO seek a finding that membership in the MISO RTO is in the public interest. Becoming a member of the MISO RTO will not affect the ownership by the Utility operating companies of their generation and transmission facilities or the responsibility for maintaining those facilities. Once the Utility operating companies are fully integrated as members, however, the MISO RTO will assume control of transmission planning and congestion management and, through its Day 2 market, the commitment and dispatch of generation that is bid into the MISO RTO’s markets. The APSC, the LPSC, and the MPSC have established procedural schedules with hearings scheduled in May/June 2012. The FERC filings related to integrating the Utility operating companies into the MISO RTO are planned for late 2012 or early 2013. The target implementation date for joining the MISO RTO is December 2013.

Entergy believes that the decision to join the MISO RTO should be evaluated separately from and independent of the decision regarding the ownership of Entergy’s transmission system, and Entergy plans to pursue the MISO RTO proposal and the planned spin-off and merger of the transmission business on parallel regulatory paths. In December 2011, however, the LPSC ALJ in the MISO RTO proceeding ordered Entergy Gulf States Louisiana and Entergy Louisiana to file testimony regarding the impact of the proposed spin-off and merger of Entergy’s transmission business on the application to join the MISO RTO. Entergy Gulf States Louisiana and Entergy Louisiana complied with this order, but also filed a notice of objection and reservation of rights in response to the order, stating that the testimony, as well as related discovery and other proceedings, are not relevant to the decision to join the MISO RTO. In the APSC proceeding regarding the MISO RTO proposal, in February 2012 the APSC ordered the parties to consider to what extent, if any, the proposed spin-off and merger of Entergy’s transmission business might affect Entergy Arkansas’s membership in an RTO or otherwise affect the proceeding. The next round of testimony in the APSC proceeding is scheduled for March 2012.

In June 2011, MISO filed with the FERC a request for a transitional waiver of provisions of its open access transmission, energy, and operating reserve markets tariff regarding allocation of transmission network upgrade costs, in order to establish a transition for the integration of the Utility operating companies. Several parties intervened in the proceeding, including Entergy, the APSC, the LPSC, and the City Council, and some of the parties also filed comments or protests. In September 2011 the FERC issued an order denying on procedural grounds MISO’s request, further advising MISO that submitting modified tariff sheets is the appropriate method for implementing the transition that MISO seeks for the Utility operating companies. The FERC did not address the merits of any transition arrangements that may be appropriate to integrate the Utility operating companies into the MISO RTO. MISO worked with its stakeholders to prepare the appropriate changes to its tariff and filed the proposed tariff changes with the FERC in November 2011. Numerous entities filed interventions and protests to MISO’s filing. On January 25, 2012, the FERC sent a letter to MISO requesting additional information relating to MISO’s proposed tariff changes.

Notice to SERC Reliability Corporation Regarding Reliability Standards and FERC Investigation

Entergy has notified the SERC Reliability Corporation (SERC) of potential violations of certain North American Electric Reliability Corporation (NERC) reliability standards, including certain Critical Infrastructure Protection, Facilities Design, Connection and Maintenance, and System Protection and Control standards. Entergy is working with the SERC to provide information concerning these potential violations. In addition, FERC’s Division of Investigations is conducting an investigation of certain issues relating to the Utility operating companies compliance with certain Reliability Standards related to protective system maintenance, facility ratings and modeling, training, and communications. The Energy Policy Act of 2005 provides authority to impose civil penalties for violations of the Federal Power Act and FERC regulations.

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Management's Financial Discussion and Analysis

U.S. Department of Justice Investigation

In September 2010, Entergy was notified that the U.S. Department of Justice had commenced a civil investigation of competitive issues concerning certain generation procurement, dispatch, and transmission system practices and policies of the Utility operating companies. The investigation is ongoing.

Market and Credit Risk Sensitive Instruments

Market risk is the risk of changes in the value of commodity and financial instruments, or in future net income or cash flows, in response to changing market conditions. Entergy holds commodity and financial instruments that are exposed to the following significant market risks:

·	The commodity price risk associated with the sale of electricity by the Entergy Wholesale Commodities business.

·	The interest rate and equity price risk associated with Entergy’s investments in pension and other postretirement benefit trust funds. See Note 11 to the financial statements for details regarding Entergy’s pension and other postretirement benefit trust funds.

·	The interest rate and equity price risk associated with Entergy’s investments in nuclear plant decommissioning trust funds, particularly in the Entergy Wholesale Commodities business. See Note 17 to the financial statements for details regarding Entergy’s decommissioning trust funds.

The interest rate risk associated with changes in interest rates as a result of Entergy’s issuances of debt. Entergy manages its interest rate exposure by monitoring current interest rates and its debt outstanding in relation to total capitalization. See Notes 4 and 5 to the financial statements for the details of Entergy’s debt outstanding.

The Utility business has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail rate regulators, the Utility operating companies hedge the exposure to natural gas price volatility of their fuel and gas purchased for resale costs, which are recovered from customers.

Entergy’s commodity and financial instruments are exposed to credit risk. Credit risk is the risk of loss from nonperformance by suppliers, customers, or financial counterparties to a contract or agreement. Entergy is also exposed to a potential demand on liquidity due to credit support requirements within its supply or sales agreements.

Commodity Price Risk

Power Generation

As a wholesale generator, Entergy Wholesale Commodities core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and sells energy in the day ahead or spot markets. In addition to selling the energy produced by its plants, Entergy Wholesale Commodities sells unforced capacity, which allows load-serving entities to meet specified reserve and related requirements placed on them by the ISOs in their respective areas. Entergy Wholesale Commodities’ forward fixed price power contracts consist of contracts to sell energy only, contracts to sell capacity only, and bundled contracts in which it sells both capacity and energy. While the terminology and payment mechanics vary in these contracts, each of these types of contracts requires Entergy Wholesale Commodities to deliver MWh of energy, make capacity available, or both. The following is a summary as of December 31, 2011 of the amount of Entergy Wholesale Commodities’ nuclear power plants’ planned energy output that is sold forward under physical or financial contracts:

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Energy
	2012	2013	2014	2015	2016

Percent of planned generation sold forward:
Unit-contingent	61%	38%	14%	12%	12%
Unit-contingent with guarantee of availability (1)	16%	19%	15%	13%	13%
Firm LD	24%	24%	10%	-%	-%
Offsetting positions	(13)%	-%	-%	-%	-%
Total energy sold forward	88%	81%	39%	25%	25%
Planned generation (TWh) (2) (3)	41	40	41	41	40
Average revenue under contract per MWh (4)	$49	$45-50	$49-54	$49-57	$50-59

Capacity
	2012	2013	2014	2015	2016

Percent of capacity sold forward:
Bundled capacity and energy contracts	18%	16%	16%	16%	16%
Capacity contracts	39%	26%	25%	11%	-%
Total capacity sold forward	57%	42%	41%	27%	16%
Planned net MW in operation (3)	4,998	4,998	4,998	4,998	4,998
Average revenue under contract per kW per month (applies to capacity contracts only)	$2.4	$3.2	$3.1	$2.9	$-
Blended Capacity and Energy Recap (based on revenues)
% of planned generation and capacity sold forward	90%	80%	43%	27%	26%
Average revenue under contract per MWh (4)	$51	$47	$51	$52	$52

(1)	A sale of power on a unit-contingent basis coupled with a guarantee of availability provides for the payment to the power purchaser of contract damages, if incurred, in the event the seller fails to deliver power as a result of the failure of the specified generation unit to generate power at or above a specified availability threshold. All of Entergy’s outstanding guarantees of availability provide for dollar limits on Entergy’s maximum liability under such guarantees.
(2)	Amount of output expected to be generated by Entergy Wholesale Commodities nuclear units considering plant operating characteristics, outage schedules, and expected market conditions which impact dispatch.
(3)	Assumes NRC license renewal for plants whose current licenses expire within five years and the continued operation of all six plants. NRC license renewal applications are in process for three units, as follows (with current license expirations in parentheses): Pilgrim (June 2012), Indian Point 2 (September 2013), and Indian Point 3 (December 2015). For a discussion regarding the continued operation of the Vermont Yankee plant, see “Impairment of Long-Lived Assets” in Note 1 to the financial statements.
(4)	Revenue on a per unit basis at which generation output, capacity, or a combination of both is expected to be sold to third parties (including offsetting positions), given existing contract or option exercise prices based on expected dispatch or capacity, excluding the revenue associated with the amortization of the below-market PPA for Palisades. Revenue may fluctuate due to factors including positive or negative basis differentials, option premiums and market prices at time of option expiration, costs to convert firm LD to unit-contingent, and other risk management costs. Also, average revenue under contract excludes payments owed under the value sharing agreement with NYPA.

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Management's Financial Discussion and Analysis

Entergy estimates that a $10 per MWh change in the annual average energy price in the markets in which the Entergy Wholesale Commodities nuclear business sells power, based on the respective year-end market conditions, planned generation volumes, and hedged positions, would have a corresponding effect on pre-tax net income of $48 million in 2012 and would have had a corresponding effect on pre-tax net income of $17 million in 2011.

Entergy’s purchase of the FitzPatrick and Indian Point 3 plants from NYPA included value sharing agreements with NYPA. In October 2007, NYPA and the subsidiaries that own the FitzPatrick and Indian Point 3 plants amended and restated the value sharing agreements to clarify and amend certain provisions of the original terms. Under the amended value sharing agreements, the Entergy subsidiaries agreed to make annual payments to NYPA based on the generation output of the Indian Point 3 and FitzPatrick plants from January 2007 through December 2014. Entergy subsidiaries will pay NYPA $6.59 per MWh for power sold from Indian Point 3, up to an annual cap of $48 million, and $3.91 per MWh for power sold from FitzPatrick, up to an annual cap of $24 million. The annual payment for each year’s output is due by January 15 of the following year. Entergy will record the liability for payments to NYPA as power is generated and sold by Indian Point 3 and FitzPatrick. In 2011, 2010, and 2009, Entergy Wholesale Commodities recorded a $72 million liability for generation during each of those years. An amount equal to the liability was recorded each year to the plant asset account as contingent purchase price consideration for the plants. This amount will be depreciated over the expected remaining useful life of the plants.

Some of the agreements to sell the power produced by Entergy Wholesale Commodities’ power plants contain provisions that require an Entergy subsidiary to provide collateral to secure its obligations under the agreements. The Entergy subsidiary is required to provide collateral based upon the difference between the current market and contracted power prices in the regions where Entergy Wholesale Commodities sells power. The primary form of collateral to satisfy these requirements is an Entergy Corporation guaranty. Cash and letters of credit are also acceptable forms of collateral. At December 31, 2011, based on power prices at that time, Entergy had liquidity exposure of $133 million under the guarantees in place supporting Entergy Wholesale Commodities transactions, $20 million of guarantees that support letters of credit, and $6 million of posted cash collateral to the ISOs. As of December 31, 2011, the liquidity exposure associated with Entergy Wholesale Commodities assurance requirements would increase by $132 million for a $1 per MMBtu increase in gas prices in both the short-and long-term markets. In the event of a decrease in Entergy Corporation’s credit rating to below investment grade, based on power prices as of December 31, 2011, Entergy would have been required to provide approximately $44 million of additional cash or letters of credit under some of the agreements.

As of December 31, 2011, substantially all of the counterparties or their guarantors for 100% of the planned energy output under contract for Entergy Wholesale Commodities nuclear plants through 2016 have public investment grade credit ratings.

Nuclear Matters

After the nuclear incident in Japan resulting from the March 2011 earthquake and tsunami, the NRC established a task force to conduct a review of processes and regulations relating to nuclear facilities in the United States. The task force issued a near term (90-day) report in July 2011 that has made recommendations, which are currently being evaluated by the NRC. It is anticipated that the NRC will issue certain orders and requests for information to nuclear plant licensees by the end of the first quarter 2012 that will begin to implement the task force’s recommendations. These orders may require U.S. nuclear operators, including Entergy, to undertake plant modifications or perform additional analyses that could, among other things, result in increased costs and capital requirements associated with operating Entergy’s nuclear plants.

Critical Accounting Estimates

The preparation of Entergy’s financial statements in conformity with generally accepted accounting principles requires management to apply appropriate accounting policies and to make estimates and judgments that can have a significant effect on reported financial position, results of operations, and cash flows. Management has identified the following accounting policies and estimates as critical because they are based on assumptions and

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Management's Financial Discussion and Analysis

measurements that involve a high degree of uncertainty, and the potential for future changes in these assumptions and measurements could produce estimates that would have a material effect on the presentation of Entergy’s financial position, results of operations, or cash flows.

Nuclear Decommissioning Costs

Entergy subsidiaries own nuclear generation facilities in both its Utility and Entergy Wholesale Commodities business units. Regulations require Entergy subsidiaries to decommission the nuclear power plants after each facility is taken out of service, and money is collected and deposited in trust funds during the facilities’ operating lives in order to provide for this obligation. Entergy conducts periodic decommissioning cost studies to estimate the costs that will be incurred to decommission the facilities. The following key assumptions have a significant effect on these estimates:

Cost Escalation Factors - Entergy’s current decommissioning cost studies include an assumption that decommissioning costs will escalate over present cost levels by annual factors ranging from approximately 2.5% to 3.5%. A 50 basis point change in this assumption could change the ultimate cost of decommissioning a facility by as much as an approximate average of 20% to 25%. To the extent that a high probability of license renewal is assumed, a change in the estimated inflation or cost escalation rate has a larger effect on the undiscounted cash flows because the rate of inflation is factored into the calculation for a longer period of time.

Timing - In projecting decommissioning costs, two assumptions must be made to estimate the timing of plant decommissioning. First, the date of the plant’s retirement must be estimated. A high probability that the plant’s license will be renewed and operate for some time beyond the original license term has currently been assumed for purposes of calculating the decommissioning liability for a number of Entergy’s nuclear units. Second, an assumption must be made whether decommissioning will begin immediately upon plant retirement, or whether the plant will be held in SAFSTOR status for later decommissioning, as permitted by applicable regulations. SAFSTOR is decommissioning a facility by placing it in a safe stable condition that is maintained until it is subsequently decontaminated and dismantled to levels that permit license termination, normally within 60 years from permanent cessation of operations. While the effect of these assumptions cannot be determined with precision, a change of assumption of either the probability of license renewal or use of a SAFSTOR period can possibly change the present value of these obligations. Future revisions to appropriately reflect changes needed to the estimate of decommissioning costs will affect net income, only to the extent that the estimate of any reduction in the liability exceeds the amount of the undepreciated asset retirement cost at the date of the revision, for unregulated portions of Entergy’s business. Any increases in the liability recorded due to such changes are capitalized and depreciated over the asset’s remaining economic life.

Spent Fuel Disposal - Federal law requires the DOE to provide for the permanent storage of spent nuclear fuel, and legislation has been passed by Congress to develop a repository at Yucca Mountain, Nevada. However, funding for the Yucca Mountain repository was almost completely eliminated from the federal budget for the current and prior years, and hearings on the facility’s NRC license have been suspended indefinitely. The DOE has not yet begun accepting spent nuclear fuel and is in non-compliance with federal law. The DOE continues to delay meeting its obligation and Entergy is continuing to pursue damages claims against the DOE for its failure to provide timely spent fuel storage. Until a federal site is available, however, nuclear plant operators must provide for interim spent fuel storage on the nuclear plant site, which can require the construction and maintenance of dry cask storage sites or other facilities. The costs of developing and maintaining these facilities can have a significant effect (as much as an average of 20% to 30% of estimated decommissioning costs). Entergy’s decommissioning studies may include cost estimates for spent fuel storage. However, these estimates could change in the future based on the timing of the opening of an appropriate facility designated by the federal government to receive spent nuclear fuel.

Technology and Regulation - Over the past several years, more practical experience with the actual decommissioning of facilities has been gained and that experience has been incorporated into Entergy’s current decommissioning cost estimates. However, given the long duration of decommissioning projects, additional experience, including technological advancements in decommissioning, could occur and affect current cost estimates. If regulations regarding nuclear decommissioning were to change, this could have a potentially significant effect on cost estimates. The effect of these potential changes is not presently determinable.

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Interest Rates - The estimated decommissioning costs that form the basis for the decommissioning liability recorded on the balance sheet are discounted to present values using a credit-adjusted risk-free rate. When the decommissioning cost estimate is significantly changed requiring a revision to the decommissioning liability and the change results in an increase in cash flows, that increase is discounted using a current credit-adjusted risk-free rate. Under accounting rules, if the revision in estimate results in a decrease in estimated cash flows, that decrease is discounted using the previous credit-adjusted risk-free rate. Therefore, to the extent that one of the factors noted above changes resulting in a significant increase in estimated cash flows, current interest rates will affect the calculation of the present value of the additional decommissioning liability.

In the first quarter 2011, System Energy recorded a revision to its estimated decommissioning cost liability for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $38.9 million reduction in its decommissioning liability, along with a corresponding reduction in the related regulatory asset.

In the fourth quarter 2011, Entergy Wholesale Commodities recorded a reduction of $34.1 million in its decommissioning cost liability for a plant as a result of a revised decommissioning cost study obtained to comply with a state regulatory requirement. The revised cost study resulted in a change in the undiscounted cash flows and a credit to decommissioning expense of $34.1 million ($21 million net-of-tax) was recorded, reflecting the excess of the reduction in the liability over the amount of undepreciated assets.

Unbilled Revenue

As discussed in Note 1 to the financial statements, Entergy records an estimate of the revenues earned for energy delivered since the latest customer billing. Each month the estimated unbilled revenue amounts are recorded as revenue and a receivable, and the prior month’s estimate is reversed. The difference between the estimate of the unbilled receivable at the beginning of the period and the end of the period is the amount of unbilled revenue recognized during the period. The estimate recorded is primarily based upon an estimate of customer usage during the unbilled period and the billed price to customers in that month. Therefore, revenue recognized may be affected by the estimated price and usage at the beginning and end of each period, in addition to changes in certain components of the calculation.

Impairment of Long-lived Assets and Trust Fund Investments

Entergy has significant investments in long-lived assets in all of its segments, and Entergy evaluates these assets against the market economics and under the accounting rules for impairment whenever there are indications that impairments may exist. This evaluation involves a significant degree of estimation and uncertainty. In the Utility business, portions of River Bend are not included in rate base, which could reduce the revenue that would otherwise be recovered for the applicable portions of its generation. In the Entergy Wholesale Commodities business, Entergy’s investments in merchant nuclear generation assets are subject to impairment if adverse market conditions arise, if a unit ceases operation, or for certain units if their operating licenses are not renewed. Entergy’s investments in merchant non-nuclear generation assets are subject to impairment if adverse market conditions arise or if a unit ceases operation.

In order to determine if Entergy should recognize an impairment of a long-lived asset that is to be held and used, accounting standards require that the sum of the expected undiscounted future cash flows from the asset be compared to the asset’s carrying value. The carrying value of the asset includes any capitalized asset retirement cost associated with the recording of an additional decommissioning liability, therefore changes in assumptions that affect the decommissioning liability can increase or decrease the carrying value of the asset subject to impairment. If the expected undiscounted future cash flows exceed the carrying value, no impairment is recorded; if such cash flows are less than the carrying value, Entergy is required to record an impairment charge to write the asset down to its fair value. If an asset is held for sale, an impairment is required to be recognized if the fair value (less costs to sell) of the asset is less than its carrying value.

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Management's Financial Discussion and Analysis

These estimates are based on a number of key assumptions, including:

Future power and fuel prices - Electricity and gas prices have been very volatile in recent years, and this volatility is expected to continue. This volatility necessarily increases the imprecision inherent in the long-term forecasts of commodity prices that are a key determinant of estimated future cash flows.

Market value of generation assets - Valuing assets held for sale requires estimating the current market value of generation assets. While market transactions provide evidence for this valuation, the market for such assets is volatile and the value of individual assets is impacted by factors unique to those assets.

·	Future operating costs - Entergy assumes relatively minor annual increases in operating costs. Technological or regulatory changes that have a significant impact on operations could cause a significant change in these assumptions.

·	Timing - Entergy currently assumes, for a number of its nuclear units, that the plant’s license will be renewed. A change in that assumption could have a significant effect on the expected future cash flows and result in a significant effect on operations.

For additional discussion regarding the continued operation of the Vermont Yankee plant, see “Impairment of Long-Lived Assets” in Note 1 to the financial statements.

Effective January 1, 2009, Entergy adopted an accounting pronouncement providing guidance regarding recognition and presentation of other-than-temporary impairments related to investments in debt securities. The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary-impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). For debt securities held as of January 1, 2009 for which an other-than-temporary impairment had previously been recognized but for which assessment under the new guidance indicates this impairment is temporary, Entergy recorded an adjustment to its opening balance of retained earnings of $11.3 million ($6.4 million net-of-tax). Entergy did not have any material other than temporary impairments relating to credit losses on debt securities in 2011, 2010, or 2009. The assessment of whether an investment in an equity security has suffered an other than temporary impairment continues to be based on a number of factors including, first, whether Entergy has the ability and intent to hold the investment to recover its value, the duration and severity of any losses, and, then, whether it is expected that the investment will recover its value within a reasonable period of time. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. As discussed in Note 1 to the financial statements, unrealized losses that are not considered temporarily impaired are recorded in earnings for Entergy Wholesale Commodities. Entergy Wholesale Commodities recorded charges to other income of $0.1 million in 2011, $1 million in 2010, and $86 million in 2009 resulting from the recognition of impairments of certain securities held in its decommissioning trust funds that are not considered temporary. Additional impairments could be recorded in 2012 to the extent that then current market conditions change the evaluation of recoverability of unrealized losses.

Qualified Pension and Other Postretirement Benefits

Entergy sponsors qualified, defined benefit pension plans which cover substantially all employees. Additionally, Entergy currently provides postretirement health care and life insurance benefits for substantially all employees who reach retirement age and meet certain eligibility requirements while still working for Entergy. Entergy’s reported costs of providing these benefits, as described in Note 11 to the financial statements, are impacted by numerous factors including the provisions of the plans, changing employee demographics, and various actuarial calculations, assumptions, and accounting mechanisms. Because of the complexity of these calculations, the long-term nature of these obligations, and the importance of the assumptions utilized, Entergy’s estimate of these costs is a critical accounting estimate for the Utility and Entergy Wholesale Commodities segments.

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Assumptions

Key actuarial assumptions utilized in determining these costs include:

·	Discount rates used in determining future benefit obligations;

·	Projected health care cost trend rates;

·	Expected long-term rate of return on plan assets;

·	Rate of increase in future compensation levels;

·	Retirement rates; and

·	Mortality rates.

Entergy reviews the first four assumptions listed above on an annual basis and adjusts them as necessary. The falling interest rate environment and volatility in the financial equity markets have impacted Entergy’s funding and reported costs for these benefits. In addition, these trends have caused Entergy to make a number of adjustments to its assumptions.

The retirement and mortality rate assumptions are reviewed every three to five years as part of an actuarial study that compares these assumptions to the actual experience of the pension and other postretirement plans. The 2011 actuarial study reviewed plan experience from 2007 through 2010. As a result of the 2011 actuarial study, changes were made to reflect the expectation that participants have longer life expectancies and different retirement patterns than previously assumed. These changes are reflected in the December 31, 2011 financial disclosures and are a significant factor in the increase in 2012 pension and other postretirement costs compared to the 2011 costs.

In selecting an assumed discount rate to calculate benefit obligations, Entergy reviews market yields on high-quality corporate debt and matches these rates with Entergy’s projected stream of benefit payments. Based on recent market trends, the discount rates used to calculate its qualified pension benefit obligation decreased from a range of 5.6% to 5.7% for its specific pension plans in 2010 to a range of 5.1% to 5.2% in 2011. The discount rate used to calculate its other postretirement benefit obligation also decreased from 5.5% in 2010 to 5.1% in 2011.

Entergy reviews actual recent cost trends and projected future trends in establishing health care cost trend rates. Based on this review, Entergy’s assumed health care cost trend rate assumption used in measuring the December 31, 2011 accumulated postretirement benefit obligation and 2012 postretirement cost was 7.75% for pre-65 retirees and 7.5% for post-65 retirees for 2012, gradually decreasing each successive year until it reaches 4.75% in 2022 and beyond for both pre-65 and post-65 retirees. Entergy’s health care cost trend rate assumption used in measuring the December 31, 2010 accumulated postretirement benefit obligation and 2011 postretirement cost was 8.5% for pre-65 retirees and 8.0% for post-65 retirees for 2011, gradually decreasing each successive year, until it reaches a 4.75% annual increase in health care costs in 2019 for pre-65 retirees and 4.75% in 2018 and beyond for post-65 retirees.

The assumed rate of increase in future compensation levels used to calculate 2011 and 2010 benefit obligations was 4.23%.

In determining its expected long-term rate of return on plan assets used in the calculation of benefit plan costs, Entergy reviews past performance, current and expected future asset allocations, and capital market assumptions of its investment consultant and investment managers.

Since 2003, Entergy has targeted an asset allocation for its qualified pension plan assets of roughly 65% equity securities and 35% fixed-income securities. Entergy completed and adopted an optimization study in 2011 for the pension assets which recommended that the target asset allocation adjust dynamically over time, based on the funded status of the plan, from its current to its ultimate allocation of 45% equity, 55% fixed income. The ultimate asset allocation is expected to be attained when the plan is 105% funded.

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The current target allocations for Entergy’s non-taxable postretirement benefit assets are 55% equity securities and 45% fixed-income securities and, for its taxable other postretirement benefit assets, 35% equity securities and 65% fixed-income securities. Entergy also completed and adopted an optimization study in 2011 for the postretirement benefit trust assets that recommends both the taxable and the non-taxable assets move to 65% equity securities and 35% fixed-income securities. Entergy plans to adjust the postretirement asset allocation during 2012.

Entergy’s expected long term rate of return on qualified pension assets used to calculate 2011, 2010 and 2009 qualified pension costs was 8.5% and will be 8.5% for 2012. Entergy’s expected long term rate of return on non-taxable other postretirement assets used to calculate other postretirement costs was 7.75% for 2011 and 2010, 8.5% for 2009 and will be 8.5% for 2012. For Entergy’s taxable postretirement assets, the expected long term rate of return was 5.5% for 2011 and 2010, 6% for 2009 and will be 6.5% in 2012.

Cost Sensitivity

The following chart reflects the sensitivity of qualified pension cost and qualified pension projected benefit obligation to changes in certain actuarial assumptions (dollars in thousands):

Actuarial Assumption	Change in Assumption	Impact on 2011 Qualified Pension Cost	Impact on Qualified Projected Benefit Obligation
	Increase/(Decrease)

Discount rate	(0.25%)	$17,145	$188,246
Rate of return on plan assets	(0.25%)	$8,863	-
Rate of increase in compensation	0.25%	$7,503	$41,227

The following chart reflects the sensitivity of postretirement benefit cost and accumulated postretirement benefit obligation to changes in certain actuarial assumptions (dollars in thousands):

Actuarial Assumption	Change in Assumption	Impact on 2011 Postretirement Benefit Cost	Impact on Accumulated Postretirement Benefit Obligation
	Increase/(Decrease)

Health care cost trend	0.25%	$8,900	$52,730
Discount rate	(0.25%)	$6,622	$62,316

Each fluctuation above assumes that the other components of the calculation are held constant.

Accounting Mechanisms

Accounting standards require an employer to recognize in its balance sheet the funded status of its benefit plans. Refer to Note 11 to the financial statements for a further discussion of Entergy’s funded status.

In accordance with pension accounting standards, Entergy utilizes a number of accounting mechanisms that reduce the volatility of reported pension costs. Differences between actuarial assumptions and actual plan results are deferred and are amortized into expense only when the accumulated differences exceed 10% of the greater of the projected benefit obligation or the market-related value of plan assets. If necessary, the excess is amortized over the average remaining service period of active employees.

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Management's Financial Discussion and Analysis

Entergy calculates the expected return on pension and other postretirement benefit plan assets by multiplying the long-term expected rate of return on assets by the market-related value (MRV) of plan assets. Entergy determines the MRV of pension plan assets by calculating a value that uses a 20-quarter phase-in of the difference between actual and expected returns. For other postretirement benefit plan assets Entergy uses fair value when determining MRV.

Costs and Funding

In 2011, Entergy’s total qualified pension cost was $154 million. Entergy anticipates 2012 qualified pension cost to be $264 million. Pension funding was approximately $400 million for 2011. Entergy’s contributions to the pension trust are currently estimated to be approximately $163 million in 2012, although the required pension contributions will not be known with more certainty until the January 1, 2012 valuations are completed by April 1, 2012. Entergy’s preliminary estimates of 2012 funding requirements indicate that the contributions will not exceed historical levels of pension contributions.

Minimum required funding calculations as determined under Pension Protection Act guidance are performed annually as of January 1 of each year and are based on measurements of the assets and funding liabilities as measured at that date. Any excess of the funding liability over the calculated fair market value of assets results in a funding shortfall which, under the Pension Protection Act, must be funded over a seven-year rolling period. The Pension Protection Act also imposes certain plan limitations if the funded percentage, which is based on a calculated fair market values of assets divided by funding liabilities, does not meet certain thresholds. For funding purposes, asset gains and losses are smoothed in to the calculated fair market value of assets and the funding liability is based upon a weighted average 24-month corporate bond rate published by the U.S. Treasury; therefore, periodic changes in asset returns and interest rates can affect funding shortfalls and future cash contributions.

Total postretirement health care and life insurance benefit costs for Entergy in 2011 were $114.7 million, including $33 million in savings due to the estimated effect of future Medicare Part D subsidies. Entergy expects 2012 postretirement health care and life insurance benefit costs to be $138.4 million. This includes a projected $31.2 million in savings due to the estimated effect of future Medicare Part D subsidies. Entergy contributed $76.1 million to its postretirement plans in 2011. Entergy’s current estimate of contributions to its other postretirement plans is approximately $80.4 million in 2012.

Federal Healthcare Legislation

The Patient Protection and Affordable Care Act (PPACA) became federal law on March 23, 2010, and, on March 30, 2010, the Health Care and Education Reconciliation Act of 2010 became federal law and amended certain provisions of the PPACA. These new federal laws change the law governing employer-sponsored group health plans, like Entergy's plans, and include, among other things, the following significant provisions:

·	A 40% excise tax on per capita medical benefit costs that exceed certain thresholds;

·	Change in coverage limits for dependents; and

·	Elimination of lifetime caps.

The total impact of PPACA is not yet determinable because technical guidance regarding application must still be issued. Additionally, ongoing litigation and discussions are in progress regarding the constitutionality of and the potential repeal of health care reform, although whether that occurs and what parts of health care reform would be invalidated or repealed is not yet known. Entergy will continue to monitor these developments to determine the possible impact on Entergy as a result of PPACA. Entergy is participating in the programs currently provided for under PPACA, such as the early retiree reinsurance program, which has provided for some limited reimbursements of certain claims for early retirees aged 55 to 64 who are not yet eligible for Medicare.

One provision of the new law that is effective in 2013 eliminates the federal income tax deduction for prescription drug expenses of Medicare beneficiaries for which the plan sponsor also receives the retiree drug subsidy under Part D. Entergy receives subsidy payments under the Medicare Part D plan and therefore in the first quarter 2010 recorded a reduction to the deferred tax asset related to the unfunded other postretirement benefit obligation. The offset was recorded in 2010 as a $16 million charge to income tax expense or, for the Utility, including each Registrant Subsidiary, as a regulatory asset.

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Management's Financial Discussion and Analysis

Other Contingencies

As a company with multi-state domestic utility operations and a history of international investments, Entergy is subject to a number of federal, state, and international laws and regulations and other factors and conditions in the areas in which it operates, which potentially subject it to environmental, litigation, and other risks. Entergy periodically evaluates its exposure for such risks and records a reserve for those matters which are considered probable and estimable in accordance with generally accepted accounting principles.

Environmental

Entergy must comply with environmental laws and regulations applicable to the handling and disposal of hazardous waste. Under these various laws and regulations, Entergy could incur substantial costs to restore properties consistent with the various standards. Entergy conducts studies to determine the extent of any required remediation and has recorded reserves based upon its evaluation of the likelihood of loss and expected dollar amount for each issue. Additional sites could be identified which require environmental remediation for which Entergy could be liable. The amounts of environmental reserves recorded can be significantly affected by the following external events or conditions:

·	Changes to existing state or federal regulation by governmental authorities having jurisdiction over air quality, water quality, control of toxic substances and hazardous and solid wastes, and other environmental matters.

·	The identification of additional sites or the filing of other complaints in which Entergy may be asserted to be a potentially responsible party.

·	The resolution or progression of existing matters through the court system or resolution by the EPA.

Litigation

Entergy is regularly named as a defendant in a number of lawsuits involving employment, customers, and injuries and damages issues, among other matters. Entergy periodically reviews the cases in which it has been named as defendant and assesses the likelihood of loss in each case as probable, reasonably estimable, or remote and records reserves for cases which have a probable likelihood of loss and can be estimated. Given the environment in which Entergy operates, and the unpredictable nature of many of the cases in which Entergy is named as a defendant, the ultimate outcome of the litigation to which Entergy is exposed has the potential to materially affect the results of operations of Entergy or Registrant Subsidiaries.

Uncertain Tax Positions

Entergy’s operations, including acquisitions and divestitures, require Entergy to evaluate risks such as the potential tax effects of a transaction, or warranties made in connection with such a transaction. Entergy believes that it has adequately assessed and provided for these types of risks, where applicable. Any provisions recorded for these types of issues, however, could be significantly affected by events such as claims made by third parties under warranties, additional transactions contemplated by Entergy, or completion of reviews of the tax treatment of certain transactions or issues by taxing authorities.

New Accounting Pronouncements

The accounting standard-setting process, including projects between the FASB and the International Accounting Standards Board (IASB) to converge U.S. GAAP and International Financial Reporting Standards, is ongoing and the FASB and the IASB are each currently working on several projects that have not yet resulted in final pronouncements. Final pronouncements that result from these projects could have a material effect on Entergy’s future net income, financial position, or cash flows.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

In May 2011 the FASB issued ASU No. 2011-4, “Fair Value Measurement (Topic 820): Amendments to Achieve Common Fair Value Measurement and Disclosure Requirements in U.S. GAAP and IFRSs,” which states that the ASU explains how to measure fair value. The ASU states that: 1) the amendments in the ASU result in common fair value measurement and disclosure requirements in U.S. GAAP and International Financial Reporting Standards; 2) consequently, the amendments change the wording used to describe many of the requirements in U.S. GAAP for measuring fair value and for disclosing information about fair value measurements; 3) for many of the requirements, the FASB does not intend for the ASU to result in a change in the application of the requirements of current U.S. GAAP; 4) some of the amendments clarify the FASB’s intent about the application of existing fair value measurement requirements; and 5) other amendments change a particular principle or requirement for measuring fair value or for disclosing information about fair value measurements. ASU No. 2011-4 is effective for Entergy for the first quarter 2012. Entergy does not expect ASU No. 2011-4 to affect materially its results of operations, financial position, or cash flows.

In September 2011 the FASB issued ASU No. 2011-8, “Intangibles – Goodwill and Other (Topic 350): Testing Goodwill for Impairment.” The amendments permit an entity to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as a basis for determining whether it is necessary to perform a quantitative goodwill impairment assessment. ASU No. 2011-8 is effective for Entergy for the first quarter 2012. ASU No. 2011-8 will have no effect on Entergy’s results of operations, financial position, or cash flows.

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ENTERGY CORPORATION AND SUBSIDIARIES

REPORT OF MANAGEMENT

Management of Entergy Corporation and its subsidiaries has prepared and is responsible for the financial statements and related financial information included in this document. To meet this responsibility, management establishes and maintains a system of internal controls over financial reporting designed to provide reasonable assurance regarding the preparation and fair presentation of financial statements in accordance with generally accepted accounting principles. This system includes communication through written policies and procedures, an employee Code of Entegrity, and an organizational structure that provides for appropriate division of responsibility and training of personnel. This system is also tested by a comprehensive internal audit program.

Entergy management assesses the effectiveness of Entergy’s internal control over financial reporting on an annual basis. In making this assessment, management uses the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in Internal Control - Integrated Framework. Management acknowledges, however, that all internal control systems, no matter how well designed, have inherent limitations and can provide only reasonable assurance with respect to financial statement preparation and presentation.

Entergy Corporation and the Registrant Subsidiaries’ independent registered public accounting firm, Deloitte & Touche LLP, has issued an attestation report on the effectiveness of Entergy’s internal control over financial reporting as of December 31, 2011, which is included herein on pages 400 through 407.

In addition, the Audit Committee of the Board of Directors, composed solely of independent Directors, meets with the independent auditors, internal auditors, management, and internal accountants periodically to discuss internal controls, and auditing and financial reporting matters. The Audit Committee appoints the independent auditors annually, seeks shareholder ratification of the appointment, and reviews with the independent auditors the scope and results of the audit effort. The Audit Committee also meets periodically with the independent auditors and the chief internal auditor without management present, providing free access to the Audit Committee.

Based on management’s assessment of internal controls using the COSO criteria, management believes that Entergy and each of the Registrant Subsidiaries maintained effective internal control over financial reporting as of December 31, 2011. Management further believes that this assessment, combined with the policies and procedures noted above, provides reasonable assurance that Entergy’s and each of the Registrant Subsidiaries’ financial statements are fairly and accurately presented in accordance with generally accepted accounting principles.

J. WAYNE LEONARD Chairman of the Board and Chief Executive Officer of Entergy Corporation	LEO P. DENAULT Executive Vice President and Chief Financial Officer of Entergy Corporation
HUGH T. MCDONALD Chairman of the Board, President, and Chief Executive Officer of Entergy Arkansas, Inc.	WILLIAM M. MOHL Chairman of the Board, President, and Chief Executive Officer of Entergy Gulf States Louisiana, L.L.C. and Entergy Louisiana, LLC
HALEY R. FISACKERLY Chairman of the Board, President, and Chief Executive Officer of Entergy Mississippi, Inc.	CHARLES L. RICE, JR. Chairman of the Board, President and Chief Executive Officer of Entergy New Orleans, Inc.
JOSEPH F. DOMINO Chairman of the Board, President, and Chief Executive Officer of Entergy Texas, Inc.	JOHN T. HERRON Chairman, President, and Chief Executive Officer of System Energy Resources, Inc.
THEODORE H. BUNTING, JR. Senior Vice President and Chief Accounting Officer (and acting principal financial officer) of Entergy Arkansas, Inc., Entergy Gulf States Louisiana, L.L.C., Entergy Louisiana, LLC, Entergy Mississippi, Inc., Entergy New Orleans, Inc., and Entergy Texas, Inc.	WANDA C. CURRY Vice President and Chief Financial Officer of System Energy Resources, Inc.

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ENTERGY CORPORATION AND SUBSIDIARIES
SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON

	2011			2010			2009			2008			2007
	(In Thousands, Except Percentages and Per Share Amounts)

Operating revenues	$	11,229,073		$	11,487,577		$	10,745,650		$	13,093,756		$	11,484,398
Income from continuing operations	$	1,367,372		$	1,270,305		$	1,251,050		$	1,240,535		$	1,159,954
Earnings per share from continuing operations:
Basic	$	7.59		$	6.72		$	6.39		$	6.39		$	5.77
Diluted	$	7.55		$	6.66		$	6.30		$	6.20		$	5.60
Dividends declared per share	$	3.32		$	3.24		$	3.00		$	3.00		$	2.58
Return on common equity		15.43	%		14.61	%		14.85	%		15.42	%		14.13	%
Book value per share, year-end	$	52.16		$	47.53		$	45.54		$	42.07		$	40.71
Total assets	$	40,701,699		$	38,685,276		$	37,561,953		$	36,616,818		$	33,643,002
Long-term obligations (1)	$	10,268,645		$	11,575,973		$	11,277,314		$	11,734,411		$	10,165,735

(1) Includes long-term debt (excluding currently maturing debt), noncurrent capital lease obligations, and subsidiary preferred stock without sinking fund that is not presented as equity on the balance sheet.

		2011			2010			2009			2008			2007
	(Dollars In Millions)
Utility Electric Operating Revenues:
Residential	$	3,369		$	3,375		$	2,999		$	3,610		$	3,228
Commercial		2,333			2,317			2,184			2,735			2,413
Industrial		2,307			2,207			1,997			2,933			2,545
Governmental		205			212			204			248			221
Total retail		8,214			8,111			7,384			9,526			8,407
Sales for resale		216			389			206			325			393
Other		244			241			290			222			246
Total	$	8,674		$	8,741		$	7,880		$	10,073		$	9,046
Utility Billed Electric Energy Sales (GWh):
Residential		36,684			37,465			33,626			33,047			33,281
Commercial		28,720			28,831			27,476			27,340			27,408
Industrial		40,810			38,751			35,638			37,843			38,985
Governmental		2,474			2,463			2,408			2,379			2,339
Total retail		108,688			107,510			99,148			100,609			102,013
Sales for resale		4,111			4,372			4,862			5,401			6,145
Total		112,799			111,882			104,010			106,010			108,158

Competitive Businesses:
Operating Revenues	$	2,390		$	2,549		$	2,693		$	2,779		$	2,232
Billed Electric Energy Sales (GWh)		43,520			42,682			43,969			44,747			40,916

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of

Entergy Corporation and Subsidiaries

New Orleans, Louisiana

We have audited the accompanying consolidated balance sheets of Entergy Corporation and Subsidiaries (the “Corporation”) as of December 31, 2011 and 2010, and the related consolidated income statements, consolidated statements of comprehensive income, consolidated statements of cash flows, and consolidated statements of changes in equity for each of the three years in the period ended December 31, 2011. These financial statements are the responsibility of the Corporation’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of Entergy Corporation and Subsidiaries as of December 31, 2011 and 2010, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2011, in conformity with accounting principles generally accepted in the United States of America.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Corporation’s internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 27, 2012 expressed an unqualified opinion on the Corporation’s internal control over financial reporting.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands, Except Share Data)

OPERATING REVENUES
Electric	$	8,673,517		$	8,740,637		$	7,880,016
Natural gas		165,819			197,658			172,213
Competitive businesses		2,389,737			2,549,282			2,693,421
TOTAL		11,229,073			11,487,577			10,745,650

OPERATING EXPENSES
Operating and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale		2,492,714			2,518,582			2,309,831
Purchased power		1,564,967			1,659,416			1,395,203
Nuclear refueling outage expenses		255,618			256,123			241,310
Other operation and maintenance		2,867,758			2,969,402			2,750,810
Decommissioning		190,595			211,736			199,063
Taxes other than income taxes		536,026			534,299			503,859
Depreciation and amortization		1,102,202			1,069,894			1,082,775
Other regulatory charges (credits) - net		205,959			44,921			(21,727	)
TOTAL		9,215,839			9,264,373			8,461,124

Gain on sale of business		-			44,173			-

OPERATING INCOME		2,013,234			2,267,377			2,284,526

OTHER INCOME
Allowance for equity funds used during construction		84,305			59,381			59,545
Interest and investment income		129,134			185,455			236,628
Other than temporary impairment losses		(140	)		(1,378	)		(86,069	)
Miscellaneous - net		(59,271	)		(48,124	)		(40,396	)
TOTAL		154,028			195,334			169,708

INTEREST EXPENSE
Interest expense		551,521			610,146			603,679
Allowance for borrowed funds used during construction		(37,894	)		(34,979	)		(33,235	)
TOTAL		513,627			575,167			570,444

INCOME BEFORE INCOME TAXES		1,653,635			1,887,544			1,883,790

Income taxes		286,263			617,239			632,740

CONSOLIDATED NET INCOME		1,367,372			1,270,305			1,251,050

Preferred dividend requirements of subsidiaries		20,933			20,063			19,958

NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION	$	1,346,439		$	1,250,242		$	1,231,092


Earnings per average common share:
Basic	$	7.59		$	6.72		$	6.39
Diluted	$	7.55		$	6.66		$	6.30
Dividends declared per common share	$	3.32		$	3.24		$	3.00

Basic average number of common shares outstanding		177,430,208			186,010,452			192,772,032
Diluted average number of common shares outstanding		178,370,695			187,814,235			195,838,068

See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands)

Net Income	$	1,367,372		$	1,270,305		$	1,251,050

Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss)
(net of tax expense (benefit) of $34,411, ($7,088), and $333)		71,239			(11,685	)		(2,887	)
Pension and other postretirement liabilities
(net of tax benefit of $131,198, $14,387, and $34,415)		(223,090	)		(8,527	)		(35,707	)
Net unrealized investment gains
(net of tax expense of $19,368, $51,130, and $102,845)		21,254			57,523			82,929
Foreign currency translation
(net of tax expense (benefit) of $192, ($182), and ($246))		357			(338	)		(457	)
Other comprehensive income (loss)		(130,240	)		36,973			43,878

Comprehensive Income		1,237,132			1,307,278			1,294,928

Preferred dividend requirements of subsidiaries		20,933			20,063			19,958

Comprehensive Income Attributable to Entergy Corporation	$	1,216,199		$	1,287,215		$	1,274,970


See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands)

OPERATING ACTIVITIES
Consolidated net income	$	1,367,372		$	1,270,305		$	1,251,050
Adjustments to reconcile consolidated net income to net cash flow
provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		1,745,455			1,705,331			1,458,861
Deferred income taxes, investment tax credits, and non-current taxes accrued		(280,029	)		718,987			864,684
Gain on sale of business		-			(44,173	)		-
Changes in working capital:
Receivables		28,091			(99,640	)		116,444
Fuel inventory		5,393			(10,665	)		19,291
Accounts payable		(131,970	)		216,635			(14,251	)
Prepaid taxes and taxes accrued		580,042			(116,988	)		(260,029	)
Interest accrued		(34,172	)		17,651			4,974
Deferred fuel		(55,686	)		8,909			72,314
Other working capital accounts		41,875			(160,326	)		(43,391	)
Change in provisions for estimated losses		(11,086	)		265,284			(12,030	)
Change in other regulatory assets		(673,244	)		339,408			(415,157	)
Change in pension and other postretirement liabilities		962,461			(80,844	)		71,789
Other		(415,685	)		(103,793	)		(181,391	)
Net cash flow provided by operating activities		3,128,817			3,926,081			2,933,158

INVESTING ACTIVITIES
Construction/capital expenditures		(2,040,027	)		(1,974,286	)		(1,931,245	)
Allowance for equity funds used during construction		86,252			59,381			59,545
Nuclear fuel purchases		(641,493	)		(407,711	)		(525,474	)
Proceeds from sale/leaseback of nuclear fuel		-			-			284,997
Proceeds from sale of assets and businesses		6,531			228,171			39,554
Payments for purchases of plants		(646,137	)		-			-
Insurance proceeds received for property damages		-			7,894			53,760
Changes in transition charge account		(7,260	)		(29,945	)		(1,036	)
NYPA value sharing payment		(72,000	)		(72,000	)		(72,000	)
Payments to storm reserve escrow account		(6,425	)		(296,614	)		(6,802	)
Receipts from storm reserve escrow account		-			9,925			-
Decrease (increase) in other investments		(11,623	)		24,956			100,956
Proceeds from nuclear decommissioning trust fund sales		1,360,346			2,606,383			2,570,523
Investment in nuclear decommissioning trust funds		(1,475,017	)		(2,730,377	)		(2,667,172	)
Net cash flow used in investing activities		(3,446,853	)		(2,574,223	)		(2,094,394	)

See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands)

FINANCING ACTIVITIES
Proceeds from the issuance of:
Long-term debt		2,990,881			3,870,694			2,003,469
Common stock and treasury stock		46,185			51,163			28,198
Retirement of long-term debt		(2,437,372	)		(4,178,127	)		(1,843,169	)
Repurchase of common stock		(234,632	)		(878,576	)		(613,125	)
Redemption of subsidiary common and preferred stock		(30,308	)		-			(1,847	)
Changes in credit borrowings - net		(6,501	)		(8,512	)		(25,000	)
Dividends paid:
Common stock		(589,605	)		(603,854	)		(576,956	)
Preferred stock		(20,933	)		(20,063	)		(19,958	)
Net cash flow used in financing activities		(282,285	)		(1,767,275	)		(1,048,388	)

Effect of exchange rates on cash and cash equivalents		287			338			(1,316	)

Net decrease in cash and cash equivalents		(600,034	)		(415,079	)		(210,940	)

Cash and cash equivalents at beginning of period		1,294,472			1,709,551			1,920,491

Cash and cash equivalents at end of period	$	694,438		$	1,294,472		$	1,709,551



SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized	$	532,271		$	534,004		$	576,811
Income taxes	$	(2,042	)	$	32,144		$	43,057

Noncash financing activities:
Long-term debt retired (equity unit notes)	$	-		$	-		$	(500,000	)
Common stock issued in settlement of equity unit purchase contracts	$	-		$	-		$	500,000

See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS

	December 31,
	2011			2010
	(In Thousands)

CURRENT ASSETS
Cash and cash equivalents:
Cash	$	81,468		$	76,290
Temporary cash investments		612,970			1,218,182
Total cash and cash equivalents		694,438			1,294,472
Securitization recovery trust account		50,304			43,044
Accounts receivable:
Customer		568,558			602,796
Allowance for doubtful accounts		(31,159	)		(31,777	)
Other		166,186			161,662
Accrued unbilled revenues		298,283			302,901
Total accounts receivable		1,001,868			1,035,582
Deferred fuel costs		209,776			64,659
Accumulated deferred income taxes		9,856			8,472
Fuel inventory - at average cost		202,132			207,520
Materials and supplies - at average cost		894,756			866,908
Deferred nuclear refueling outage costs		231,031			218,423
System agreement cost equalization		36,800			52,160
Prepaid taxes		-			301,807
Prepayments and other		291,742			246,036
TOTAL		3,622,703			4,339,083

OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity		44,876			40,697
Decommissioning trust funds		3,788,031			3,595,716
Non-utility property - at cost (less accumulated depreciation)		260,436			257,847
Other		416,423			405,946
TOTAL		4,509,766			4,300,206

PROPERTY, PLANT AND EQUIPMENT
Electric		39,385,524			37,153,061
Property under capital lease		809,449			800,078
Natural gas		343,550			330,608
Construction work in progress		1,779,723			1,661,560
Nuclear fuel		1,546,167			1,377,962
TOTAL PROPERTY, PLANT AND EQUIPMENT		43,864,413			41,323,269
Less - accumulated depreciation and amortization		18,255,128			17,474,914
PROPERTY, PLANT AND EQUIPMENT - NET		25,609,285			23,848,355

DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Regulatory asset for income taxes - net		799,006			845,725
Other regulatory assets (includes securitization property of
$1,009,103 as of December 31, 2011 and $882,346 as of
December 31, 2010)		4,636,871			3,838,237
Deferred fuel costs		172,202			172,202
Goodwill		377,172			377,172
Accumulated deferred income taxes		19,003			54,523
Other		955,691			909,773
TOTAL		6,959,945			6,197,632

TOTAL ASSETS	$	40,701,699		$	38,685,276

See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY

	December 31,
	2011			2010
	(In Thousands)

CURRENT LIABILITIES
Currently maturing long-term debt	$	2,192,733		$	299,548
Notes payable		108,331			154,135
Accounts payable		1,069,096			1,181,099
Customer deposits		351,741			335,058
Taxes accrued		278,235			-
Accumulated deferred income taxes		99,929			49,307
Interest accrued		183,512			217,685
Deferred fuel costs		255,839			166,409
Obligations under capital leases		3,631			3,388
Pension and other postretirement liabilities		44,031			39,862
System agreement cost equalization		80,090			52,160
Other		283,531			277,598
TOTAL		4,950,699			2,776,249

NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued		8,096,452			8,573,646
Accumulated deferred investment tax credits		284,747			292,330
Obligations under capital leases		38,421			42,078
Other regulatory liabilities		728,193			539,026
Decommissioning and asset retirement cost liabilities		3,296,570			3,148,479
Accumulated provisions		385,512			395,250
Pension and other postretirement liabilities		3,133,657			2,175,364
Long-term debt (includes securitization bonds of $1,070,556 as of
December 31, 2011 and $931,131 as of December 31, 2010)		10,043,713			11,317,157
Other		501,954			618,559
TOTAL		26,509,219			27,101,889

Commitments and Contingencies

Subsidiaries' preferred stock without sinking fund		186,511			216,738

EQUITY
Common Shareholders' Equity:
Common stock, $.01 par value, authorized 500,000,000 shares;
issued 254,752,788 shares in 2011 and in 2010		2,548			2,548
Paid-in capital		5,360,682			5,367,474
Retained earnings		9,446,960			8,689,401
Accumulated other comprehensive loss		(168,452	)		(38,212	)
Less - treasury stock, at cost (78,396,988 shares in 2011 and
76,006,920 shares in 2010)		5,680,468			5,524,811
Total common shareholders' equity		8,961,270			8,496,400
Subsidiaries' preferred stock without sinking fund		94,000			94,000
TOTAL		9,055,270			8,590,400

TOTAL LIABILITIES AND EQUITY	$	40,701,699		$	38,685,276

See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Years Ended December 31, 2011, 2010, and 2009

				Common Shareholders’ Equity
	Subsidiaries’ Preferred Stock			Common Stock		Treasury Stock			Paid-in Capital			Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Total
	(In Thousands)

Balance at December 31, 2008	$	94,000		$	2,482	$	(4,175,214	)	$	4,869,303		$	7,382,719		$	(112,698	)	$	8,060,592


Consolidated net income (a)		19,958			-		-			-			1,231,092			-			1,251,050
Other comprehensive income		-			-		-			-			-			43,878			43,878
Common stock repurchases		-			-		(613,125	)		-			-			-			(613,125	)
Common stock issuances in settlement of equity unit purchase contracts		-			66		-			499,934			-			-			500,000
Common stock issuances related to stock plans		-			-		61,172			805			-			-			61,977
Common stock dividends declared		-			-		-			-			(576,913	)		-			(576,913	)
Preferred dividend requirements of subsidiaries (a)		(19,958	)		-		-			-			-			-			(19,958	)
Capital stock and other expenses		-			-		-			-			(141	)		-			(141	)
Adjustment for implementation of new accounting pronouncement		-			-		-			-			6,365			(6,365	)		-

Balance at December 31, 2009	$	94,000		$	2,548	$	(4,727,167	)	$	5,370,042		$	8,043,122		$	(75,185	)	$	8,707,360


Consolidated net income (a)		20,063			-		-			-			1,250,242			-			1,270,305
Other comprehensive income		-			-		-			-			-			36,973			36,973
Common stock repurchases		-			-		(878,576	)		-			-			-			(878,576	)
Common stock issuances related to stock plans		-			-		80,932			(2,568	)		-			-			78,364
Common stock dividends declared		-			-		-			-			(603,963	)		-			(603,963	)
Preferred dividend requirements of subsidiaries (a)		(20,063	)		-		-			-			-			-			(20,063	)

Balance at December 31, 2010	$	94,000		$	2,548	$	(5,524,811	)	$	5,367,474		$	8,689,401		$	(38,212	)	$	8,590,400


Consolidated net income (a)		20,933			-		-			-			1,346,439			-			1,367,372
Other comprehensive loss		-			-		-			-			-			(130,240	)		(130,240	)
Common stock repurchases		-			-		(234,632	)		-			-			-			(234,632	)
Common stock issuances related to stock plans		-			-		78,975			(6,792	)		-			-			72,183
Common stock dividends declared		-			-		-			-			(588,880	)		-			(588,880	)
Preferred dividend requirements of subsidiaries (a)		(20,933	)		-		-			-			-			-			(20,933	)

Balance at December 31, 2011	$	94,000		$	2,548	$	(5,680,468	)	$	5,360,682		$	9,446,960		$	(168,452	)	$	9,055,270


See Notes to Financial Statements.

(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2011, 2010, and 2009 include $13.3 million of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented as equity.

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ENTERGY CORPORATION AND SUBSIDIARIES

NOTES TO FINANCIAL STATEMENTS

NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

The accompanying consolidated financial statements include the accounts of Entergy Corporation and its subsidiaries. As required by generally accepted accounting principles in the United States of America, all intercompany transactions have been eliminated in the consolidated financial statements. Entergy’s Registrant Subsidiaries (Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) also include their separate financial statements in this Form 10-K. The Registrant Subsidiaries and many other Entergy subsidiaries maintain accounts in accordance with FERC and other regulatory guidelines. Certain previously reported amounts have been reclassified to conform to current classifications, with no effect on net income or common shareholders’ (or members’) equity.

Use of Estimates in the Preparation of Financial Statements

In conformity with generally accepted accounting principles in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used.

Revenues and Fuel Costs

Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, and Entergy Texas generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Louisiana, Mississippi, and Texas, respectively. Entergy Gulf States Louisiana also distributes natural gas to retail customers in and around Baton Rouge, Louisiana. Entergy New Orleans sells both electric power and natural gas to retail customers in the City of New Orleans, except for Algiers, where Entergy Louisiana is the electric power supplier. The Entergy Wholesale Commodities segment derives almost all of its revenue from sales of electric power generated by plants owned by subsidiaries in that segment.

Entergy recognizes revenue from electric power and natural gas sales when power or gas is delivered to customers. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating companies accrue an estimate of the revenues for energy delivered since the latest billings. The Utility operating companies calculate the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and prices in effect in Entergy’s Utility operating companies’ various jurisdictions. Changes are made to the inputs in the estimate as needed to reflect changes in billing practices. Each month the estimated unbilled revenue amounts are recorded as revenue and unbilled accounts receivable, and the prior month’s estimate is reversed. Therefore, changes in price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the next, and may result in variability in reported revenues from one period to the next as prior estimates are reversed and new estimates recorded.

Entergy records revenue from sales under rates implemented subject to refund less estimated amounts accrued for probable refunds when Entergy believes it is probable that revenues will be refunded to customers based upon the status of the rate proceeding as of the date the financial statements are prepared.

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Notes to Financial Statements

Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where the fuel component of revenues is billed based on a pre-determined fuel cost (fixed fuel factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing.System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital costs are computed by allowing a return on System Energy’s common equity funds allocable to its net investment in Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf.

Property, Plant, and Equipment

Property, plant, and equipment is stated at original cost. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens.

Electric plant includes the portions of Grand Gulf and Waterford 3 that have been sold and leased back. For financial reporting purposes, these sale and leaseback arrangements are reflected as financing transactions.

Net property, plant, and equipment for Entergy (including property under capital lease and associated accumulated amortization) by business segment and functional category, as of December 31, 2011 and 2010, is shown below:

2011	Entergy	Utility	Entergy Wholesale Commodities	Parent & Other
	(In Millions)
Production
Nuclear	$8,635	$5,441	$3,194	$-
Other	2,431	2,032	399	-
Transmission	3,344	3,309	35	-
Distribution	6,157	6,157	-	-
Other	1,716	1,463	250	3
Construction work in progress	1,780	1,420	359	1
Nuclear fuel	1,546	802	744	-
Property, plant, and equipment - net	$25,609	$20,624	$4,981	$4

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Notes to Financial Statements

2010	Entergy	Utility	Entergy Wholesale Commodities	Parent & Other
	(In Millions)
Production
Nuclear	$8,393	$5,378	$3,015	$-
Other	1,842	1,797	45	-
Transmission	2,986	2,956	30	-
Distribution	5,926	5,926	-	-
Other	1,661	1,411	248	2
Construction work in progress	1,662	1,300	361	1
Nuclear fuel	1,378	760	618	-
Property, plant, and equipment - net	$23,848	$19,528	$4,317	$3

Depreciation rates on average depreciable property for Entergy approximated 2.6% in 2011, 2.6% in 2010, and 2.7% in 2009. Included in these rates are the depreciation rates on average depreciable utility property of 2.5% in 2011, 2.5% in 2010, and 2.7% 2009, and the depreciation rates on average depreciable non-utility property of 3.9% in 2011, 3.7% in 2010, and 3.8% in 2009.

Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in fuel expense in the income statements.

“Non-utility property - at cost (less accumulated depreciation)” for Entergy is reported net of accumulated depreciation of $214.3 million and $207.6 million as of December 31, 2011 and 2010, respectively.

Construction expenditures included in accounts payable at December 31, 2011 is $171 million.

Net property, plant, and equipment for the Registrant Subsidiaries (including property under capital lease and associated accumulated amortization) by company and functional category, as of December 31, 2011 and 2010, is shown below:

2011	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Millions)
Production
Nuclear	$1,034	$1,458	$1,561	$-	$-	$-	$1,388
Other	398	286	679	350	(7)	325	-
Transmission	942	500	706	510	22	624	5
Distribution	1,700	856	1,304	1,009	298	990	-
Other	173	192	278	206	186	110	18
Construction work in progress	120	122	559	105	14	91	358
Nuclear fuel	273	206	165	-	-	-	158
Property, plant, and equipment - net	$4,640	$3,620	$5,252	$2,180	$513	$2,140	$1,927

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Notes to Financial Statements

2010	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Millions)
Production
Nuclear	$1,029	$1,452	$1,489	$-	$-	$-	$1,408
Other	406	302	393	368	(2)	331	-
Transmission	837	456	597	469	22	569	6
Distribution	1,637	817	1,255	977	296	944	-
Other	197	192	289	207	180	116	20
Construction work in progress	114	119	521	147	12	80	211
Nuclear fuel	189	203	135	-	-	-	155
Property, plant, and equipment - net	$4,409	$3,541	$4,679	$2,168	$508	$2,040	$1,800

Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below:

	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy

2011	2.6%	1.8%	2.5%	2.6%	3.0%	2.2%	2.8%
2010	2.9%	1.8%	2.4%	2.6%	3.1%	2.3%	2.9%
2009	3.3%	1.9%	2.5%	2.6%	3.0%	2.3%	2.9%

Non-utility property - at cost (less accumulated depreciation) for Entergy Gulf States Louisiana is reported net of accumulated depreciation of $136 million and $134 million as of December 31, 2011 and 2010, respectively. Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $2.7 million and $2.5 million as of December 31, 2011 and 2010, respectively. Non-utility property - at cost (less accumulated depreciation) for Entergy Texas is reported net of accumulated depreciation of $9.8 million and $9.5 million as of December 31, 2011 and 2010, respectively.

As of December 31, 2011, construction expenditures included in accounts payable are $14.1 million for Entergy Arkansas, $13.7 million for Entergy Gulf States Louisiana, $27 million for Entergy Louisiana, $4.3 million for Entergy Mississippi, $3.6 million for Entergy New Orleans, $4.3 million for Entergy Texas, and $32.9 million for System Energy.

Jointly-Owned Generating Stations

Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. The investments and expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2011, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows:

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Generating Stations		Fuel-Type	Total Megawatt Capability (1)	Ownership	Investment	Accumulated Depreciation
					(In Millions)
Utility business:
Entergy Arkansas -
Independence	Unit 1	Coal	836	31.50%	$128	$96
	Common Facilities	Coal		15.75%	$33	$24
White Bluff	Units 1 and 2	Coal	1,659	57.00%	$494	$337
Ouachita (2)	Common Facilities	Gas		66.67%	$171	$142
Entergy Gulf States Louisiana -
Roy S. Nelson	Unit 6	Coal	550	40.25%	$244	$172
Roy S. Nelson	Unit 6 Common Facilities	Coal		15.92%	$9	$3
Big Cajun 2	Unit 3	Coal	588	24.15%	$142	$97
Ouachita (2)	Common Facilities	Gas		33.33%	$87	$72
Entergy Louisiana -
Acadia	Common Facilities	Gas		50.00%	$12	$-
Entergy Mississippi -
Independence	Units 1 and 2 and Common Facilities	Coal	1,678	25.00%	$249	$137
Entergy Texas -
Roy S. Nelson	Unit 6	Coal	550	29.75%	$178	$117
Roy S. Nelson	Unit 6 Common Facilities	Coal		11.77%	$6	$2
Big Cajun 2	Unit 3	Coal	588	17.85%	$107	$68
System Energy -
Grand Gulf	Unit 1	Nuclear	1,190	90.00%(3)	$3,929	$2,518

Entergy Wholesale Commodities:
Independence	Unit 2	Coal	842	14.37%	$68	$41
Independence	Common Facilities	Coal		7.18%	$16	$10
Roy S. Nelson	Unit 6	Coal	550	10.9%	$102	$53
Roy S. Nelson	Unit 6 Common Facilities	Coal		4.31%	$2	$1

(1)	“Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.
(2)	Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Gulf States Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units.
(3)	Includes an 11.5% leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 10 to the financial statements.

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Notes to Financial Statements

Nuclear Refueling Outage Costs

Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line.

Allowance for Funds Used During Construction (AFUDC)

AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers.

Income Taxes

Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreement. Deferred income taxes are recorded for all temporary differences between the book and tax basis of assets and liabilities, and for certain credits available for carryforward.

Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted.

Investment tax credits are deferred and amortized based upon the average useful life of the related property, in accordance with ratemaking treatment.

Earnings per Share

The following table presents Entergy’s basic and diluted earnings per share calculation included on the consolidated statements of income:

	For the Years Ended December 31,
	2011			2010			2009
		(In Millions, Except Per Share Data)
Basic earnings per average common share	Income	Shares	$/share	Income	Shares	$/share	Income	Shares	$/share
Net income attributable to Entergy Corporation	$1,346.4	177.4	$7.59	$1,250.2	186.0	$6.72	$1,231.1	192.8	$6.39
Average dilutive effect of:
Stock options	-	1.0	(0.04)	-	1.8	(0.06)	-	2.2	(0.07)
Equity units	-	-	-	-	-	-	3.2	0.8	(0.02)
Diluted earnings per average common share	$1,346.4	178.4	$7.55	$1,250.2	187.8	$6.66	$1,234.3	195.8	$6.30

The calculation of diluted earnings per share excluded 5,712,604 options outstanding at December 31, 2011, 5,380,262 options outstanding at December 31, 2010, and 4,368,614 options outstanding at December 31, 2009 that could potentially dilute basic earnings per share in the future. Those options were not included in the calculation of diluted earnings per share because the exercise price of those options exceeded the average market price for the year.

See Note 7 to the financial statements for a discussion of the equity units.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Stock-based Compensation Plans

Entergy grants stock options to key employees of the Entergy subsidiaries, which is described more fully in Note 12 to the financial statements. Entergy accounts for stock options using the fair value based method. Awards under Entergy’s plans generally vest over three years.

Accounting for the Effects of Regulation

Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity’s balance sheet.

An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further write-offs of plant assets.

Entergy Gulf States Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated portion of River Bend, the 30% interest in River Bend formerly owned by Cajun, and its steam business. The Louisiana retail deregulated portion of River Bend is operated under a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues, and expenses established under a 1992 LPSC order. The plan allows Entergy Gulf States Louisiana to sell the electricity from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with certain provisions for sharing incremental revenue above 4.6 cents per kWh between ratepayers and shareholders.

Cash and Cash Equivalents

Entergy considers all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at date of purchase to be cash equivalents.

Allowance for Doubtful Accounts

The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable balances. The allowance is based on accounts receivable agings, historical experience, and other currently available evidence. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements.

Investments

Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the portion of River Bend that is not rate-regulated, Entergy Gulf States Louisiana has recorded an offsetting amount of unrealized gains/(losses) in other deferred credits. Decommissioning trust funds for Pilgrim, Indian Point 2, Vermont Yankee, and Palisades do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains recorded on the assets in these trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity because these assets are classified as available for sale. Unrealized losses (where cost exceeds fair market value) on the assets in these trust funds are also recorded in the accumulated other comprehensive income component of

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). The assessment of whether an investment in an equity security has suffered an other-than-temporary impairment is based on a number of factors including, first, whether Entergy has the ability and intent to hold the investment to recover its value, the duration and severity of any losses, and, then, whether it is expected that the investment will recover its value within a reasonable period of time. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. See Note 17 to the financial statements for details on the decommissioning trust funds and other than temporary impairments recorded in 2011, 2010, and 2009.

Equity Method Investments

Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s ownership level results in significant influence, but not control, over the investee and its operations. Entergy records its share of earnings or losses of the investee based on the change during the period in the estimated liquidation value of the investment, assuming that the investee’s assets were to be liquidated at book value. In accordance with this method, earnings are allocated to owners or members based on what each partner would receive from its capital account if, hypothetically, liquidation were to occur at the balance sheet date and amounts distributed were based on recorded book values. Entergy discontinues the recognition of losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any advances made or commitments to provide additional financial support. See Note 14 to the financial statements for additional information regarding Entergy’s equity method investments.

Derivative Financial Instruments and Commodity Derivatives

The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase, normal sales criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction.

Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered.

For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. The ineffective portions of all hedges are recognized in current-period earnings.

Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using bid prices and market quotes. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments held by regulated businesses may be reflected in future rates and therefore do not accrue to the benefit or detriment of stockholders. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 16 to the financial statements for further discussion of fair value.

Impairment of Long-Lived Assets

Three nuclear power plants in the Entergy Wholesale Commodities business segment (Pilgrim, Indian Point 2 and Indian Point 3) have applications pending for renewed NRC licenses. Various parties have expressed opposition to renewal of the licenses. Under federal law, nuclear power plants may continue to operate beyond their license expiration dates while their renewal applications are pending NRC approval. If the NRC does not renew the operating license for any of these plants, the plant’s operating life could be shortened, reducing its projected net cash flows and impairing its value as an asset.

In March 2011 the NRC renewed Vermont Yankee’s operating license for an additional 20 years. The renewed operating license expires in March 2032. In May 2011, the Vermont Department of Public Service and the New England Coalition petitioned the United States Court of Appeals for the D.C. Circuit seeking judicial review of the NRC’s issuance of the renewed operating license, alleging that the license had been issued without a valid and effective water quality certification under Section 401 of the Clean Water Act. Entergy Nuclear Vermont Yankee and Entergy Nuclear Operations, Inc. intervened in the proceeding. Motions by the parties for summary disposition were denied by the court, and oral argument is scheduled for May 2012.

Vermont Yankee also is operating under a Certificate of Public Good from the State of Vermont that expires in March 2012, but has an application pending before the Vermont Public Service Board (VPSB) for a new Certificate of Public Good for operation until March 2032. As the United States district court noted in its decision discussed below (regarding Entergy’s challenge to certain conditions imposed by Vermont), title 3, section 814 of the Vermont Statutes provides that a license subject to an agency’s notice and hearing requirements does not expire until a final determination on an application for renewal has been made.

In April 2011, Entergy Nuclear Vermont Yankee and Entergy Nuclear Operations, the owner and operator respectively of Vermont Yankee, filed suit in the United States District Court for the District of Vermont. The suit challenged certain conditions imposed by Vermont upon Vermont Yankee’s continued operation and storage of spent nuclear fuel, including the requirement to obtain not only a new Certificate of Public Good, but also approval by Vermont’s General Assembly. In January 2012 the court entered judgment in Entergy’s favor and specifically:

·	Declared that Vermont’s laws requiring Vermont Yankee to cease operation in March 2012 and prohibiting the storage of spent nuclear fuel from operation after that date, absent approval by the General Assembly, were based on radiological safety concerns and are preempted by the Atomic Energy Act;

·	Permanently enjoined Vermont from enforcing these preempted requirements of the state’s laws; and

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Permanently enjoined Vermont under the Commerce Clause of the United States Constitution from conditioning the issuance of a new Certificate of Public Good upon the existence of a below wholesale market power sale agreement with Vermont utilities or Vermont Yankee’s selling power to Vermont utilities at rates below those available to wholesale customers in other states.

In February 2012 the Vermont defendants filed a notice of appeal of the decision to the United States Court of Appeals for the Second Circuit.

In January 2012, Entergy filed a motion requesting that the VPSB grant, based on the existing record in its proceeding, Vermont Yankee’s pending application for a new Certificate of Public Good. The VPSB scheduled a status conference for March 9, 2012, and requested comments from the parties by March 2, 2012. In a February 23, 2012 memorandum to the parties, the VPSB asked that the parties’ comments respond to certain questions relating to, among other issues, the VPSB’s authority to issue the Certificate of Public Good and Vermont Yankee’s authority to operate beyond March 21, 2012 and store spent fuel from such operations, despite the decision and order of the United States district court.

In light of these questions from the VPSB, Vermont Yankee filed a cross-appeal of the district court’s decision. Vermont Yankee also filed two motions with the district court asking it (1) to issue an injunction prohibiting Vermont from taking any action to force Vermont Yankee to shut down during the appeal of the district court’s decision or during the Certificate of Public Good proceeding before the VPSB and any judicial appeal from that proceeding, and (2) to amend the district court’s final judgment to include certain additional provisions of Vermont law relating to Vermont Yankee’s operation and storage of spent nuclear fuel from operation after March 21, 2012, that were part of the statutes the court found to be preempted in its decision, but which were not specifically included in the final judgment.

Entergy Wholesale Commodities’ investments are subject to impairment if adverse market conditions arise, if a unit ceases operation, or for certain units if their authorizations to operate are not renewed. Specifically regarding Vermont Yankee, if Entergy concludes that Vermont Yankee is unlikely to operate significantly beyond its original license expiration date in March 2012, it could result in an impairment of part or all of the carrying value of the plant. In preparing its 2011 financial statements, Entergy evaluated whether the carrying value of Vermont Yankee was impaired as of December 31, 2011, before the outcome of the federal court lawsuit was known. For purposes of that evaluation, Entergy considered a number of factors associated with the plant’s continued operation, including the status of the federal lawsuit, the status of the state regulatory issues as described above, the potential sale of the plant, and the application of federal laws regarding the continued operation of nuclear facilities. Based on its evaluation of those factors, Entergy determined that the carrying value of Vermont Yankee was not impaired as of December 31, 2011. As of December 31, 2011 the net carrying value of the plant, including nuclear fuel, is $465 million.

River Bend AFUDC

The River Bend AFUDC gross-up is a regulatory asset that represents the incremental difference imputed by the LPSC between the AFUDC actually recorded by Entergy Gulf States Louisiana on a net-of-tax basis during the construction of River Bend and what the AFUDC would have been on a pre-tax basis. The imputed amount was only calculated on that portion of River Bend that the LPSC allowed in rate base and is being amortized through August 2025.

Reacquired Debt

The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Gulf States Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, in accordance with ratemaking treatment.

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Notes to Financial Statements

Taxes Imposed on Revenue-Producing Transactions

Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority.

Presentation of Preferred Stock without Sinking Fund

Accounting standards regarding non-controlling interests and the classification and measurement of redeemable securities require the classification of preferred securities between liabilities and shareholders’ equity on the balance sheet if the holders of those securities have protective rights that allow them to gain control of the board of directors in certain circumstances. These rights would have the effect of giving the holders the ability to potentially redeem their securities, even if the likelihood of occurrence of these circumstances is considered remote. The Entergy Arkansas, Entergy Mississippi, and Entergy New Orleans articles of incorporation provide, generally, that the holders of each company’s preferred securities may elect a majority of the respective company’s board of directors if dividends are not paid for a year, until such time as the dividends in arrears are paid. Therefore, Entergy Arkansas, Entergy Mississippi, and Entergy New Orleans present their preferred securities outstanding between liabilities and shareholders’ equity on the balance sheet. Entergy Gulf States Louisiana and Entergy Louisiana, both organized as limited liability companies, have outstanding preferred securities with similar protective rights with respect to unpaid dividends, but provide for the election of board members that would not constitute a majority of the board; and their preferred securities are therefore classified for all periods presented as a component of members’ equity.

The outstanding preferred securities of Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Asset Management (whose preferred holders also had protective rights until the securities were repurchased in December 2011), are similarly presented between liabilities and equity on Entergy’s consolidated balance sheets and the outstanding preferred securities of Entergy Gulf States Louisiana and Entergy Louisiana are presented within total equity in Entergy’s consolidated balance sheets. The preferred dividends or distributions paid by all subsidiaries are reflected for all periods presented outside of consolidated net income.

New Accounting Pronouncements

In September 2011 the FASB issued ASU No. 2011-8, “Intangibles – Goodwill and Other (Topic 350): Testing Goodwill for Impairment.” The amendments permit an entity to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount as a basis for determining whether it is necessary to perform a quantitative goodwill impairment assessment. ASU No. 2011-8 is effective for Entergy for the first quarter 2012. The adoption of ASU No. 2011-8 will have no effect on Entergy’s results of operations, financial position, or cash flows.

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Notes to Financial Statements

NOTE 2. RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Regulatory Assets

Other Regulatory Assets

Regulatory assets represent probable future revenues associated with costs that are expected to be recovered from customers through the regulatory ratemaking process affecting the Utility business. In addition to the regulatory assets that are specifically disclosed on the face of the balance sheets, the tables below provide detail of “Other regulatory assets” that are included on Entergy’s and the Registrant Subsidiaries’ balance sheets as of December 31, 2011 and 2010:

Entergy

	2011	2010
	(In Millions)
Asset Retirement Obligation - recovery dependent upon timing of decommissioning (Note 9) (b)	$395.9	$406.4
Deferred capacity (Note 2 – Retail Rate Proceedings – Filings with the LPSC)	-	15.8
Grand Gulf fuel - non-current and power management rider - recovered through rate riders when rates are redetermined periodically (Note 2 – Fuel and purchased power cost recovery)	12.4	17.4
New nuclear generation development costs (Note 2)	56.8	-
Gas hedging costs - recovered through fuel rates	30.3	1.9
Pension & postretirement costs (Note 11 – Qualified Pension Plans, Other Postretirement Benefits, and Non-Qualified Pension Plans) (b)	2,542.0	1,734.7
Postretirement benefits - recovered through 2012 (Note 11 – Other Postretirement Benefits) (b)	2.4	4.8
Provision for storm damages, including hurricane costs - recovered through securitization, insurance proceeds, and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators)	996.4	1,026.0
Removal costs - recovered through depreciation rates (Note 9) (b)	81.2	81.5
River Bend AFUDC - recovered through August 2025 (Note 1 – River Bend AFUDC)	24.3	26.2
Sale-leaseback deferral (Note 10 – Sale and Leaseback Transactions – Grand Gulf Lease Obligations)	-	22.3
Spindletop gas storage facility - recovered through December 2032 (a)	31.0	32.6
Transition to competition costs - recovered over a 15-year period through February 2021	89.2	95.8
Little Gypsy cost proceeding – recovered through securitization (Note 5 – Entergy Louisiana Securitization Bonds - Little Gypsy)	198.4	200.9
Incremental ice storm costs - recovered through 2032	10.5	11.1
Michoud plant maintenance – recovered over a 7-year period through September 2018	12.9	-
Unamortized loss on reacquired debt - recovered over term of debt	108.8	122.5
Other	44.4	38.3
Total	$4,636.9	$3,838.2

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Entergy Arkansas

	2011	2010
	(In Millions)
Asset Retirement Obligation - recovery dependent upon timing of decommissioning (Note 9) (b)	$187.7	$167.3
Incremental ice storm costs - recovered through 2032	10.5	11.1
Pension & postretirement costs (Note 11 – Qualified Pension Plans, Other Postretirement Benefits, and Non-Qualified Pension Plans) (b)	768.3	547.5
Grand Gulf fuel - non-current - recovered through rate riders when rates are redetermined periodically (Note 2 – Fuel and purchased power cost recovery)	4.6	-
Postretirement benefits - recovered through 2012 (Note 11 – Other Postretirement Benefits) (b)	2.4	4.8
Provision for storm damages - recovered either through securitization or retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators)	114.7	118.5
Unamortized loss on reacquired debt - recovered over term of debt	34.7	38.0
Other	4.0	5.2
Entergy Arkansas Total	$1,126.9	$892.4

Entergy Gulf States Louisiana

	2011	2010
	(In Millions)
Asset Retirement Obligation - recovery dependent upon timing of decommissioning (Note 9) (b)	$12.8	$17.8
Gas hedging costs - recovered through fuel rates	8.6	1.0
Pension & postretirement costs (Note 11 – Qualified Pension Plans and Non-Qualified Pension Plans) (b)	231.3	157.4
Provision for storm damages, including hurricane costs - recovered through retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators)	10.2	6.0
Deferred capacity (Note 2 – Retail Rate Proceedings – Filings with the LPSC)	-	14.0
River Bend AFUDC - recovered through August 2025 (Note 1 – River Bend AFUDC)	24.3	26.2
Spindletop gas storage facility - recovered through December 2032 (a)	31.0	32.6
Unamortized loss on reacquired debt - recovered over term of debt	11.6	13.5
Other	4.1	2.4
Entergy Gulf States Louisiana Total	$333.9	$270.9

Entergy Louisiana

	2011	2010
	(In Millions)
Asset Retirement Obligation - recovery dependent upon timing of decommissioning (Note 9) (b)	$125.8	$113.4
Gas hedging costs - recovered through fuel rates	12.4	0.4
Pension & postretirement costs (Note 11 – Qualified Pension Plans and Non-Qualified Pension Plans) (b)	427.9	309.1
Little Gypsy cost proceeding – recovered through securitization (Note 5 – Entergy Louisiana Securitization Bonds - Little Gypsy)	198.4	200.9
Provision for storm damages, including hurricane costs - recovered through retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators)	9.7	1.0
Deferred capacity (Note 2 – Retail Rate Proceedings – Filings with the LPSC)	-	1.8
Unamortized loss on reacquired debt - recovered over term of debt	20.0	22.5
Other	20.3	13.6
Entergy Louisiana Total	$814.5	$662.7

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Notes to Financial Statements

Entergy Mississippi

	2011	2010
	(In Millions)
Asset Retirement Obligation - recovery dependent upon timing of decommissioning (Note 9) (b)	$5.3	$5.0
Gas hedging costs - recovered through fuel rates	7.8	-
Removal costs - recovered through depreciation rates (Note 9) (b)	48.5	46.1
Grand Gulf fuel - non-current and power management rider- recovered through rate riders when rates are redetermined periodically (Note 2 – Fuel and purchased power cost recovery)	7.8	17.4
New nuclear generation development costs (Note 2)	56.8	-
Pension & postretirement costs (Note 11 – Qualified Pension Plans, Other Postretirement Benefits, and Non-Qualified Pension Plans) (b)	221.1	160.0
Provision for storm damages - recovered through retail rates	30.7	8.7
Unamortized loss on reacquired debt - recovered over term of debt	10.7	11.5
Other	4.7	4.5
Entergy Mississippi Total	$393.4	$253.2

Entergy New Orleans

	2011	2010
	(In Millions)
Asset Retirement Obligation - recovery dependent upon timing of decommissioning (Note 9) (b)	$3.4	$3.2
Removal costs - recovered through depreciation rates (Note 9) (b)	16.3	15.4
Gas hedging costs - recovered through fuel rates	1.5	0.5
Pension & postretirement costs (Note 11 – Qualified Pension Plans, Other Postretirement Benefits, and Non-Qualified Pension Plans) (b)	127.6	95.3
Provision for storm damages, including hurricane costs - recovered through insurance proceeds and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators)	8.6	10.8
Unamortized loss on reacquired debt - recovered over term of debt	2.6	3.0
Michoud plant maintenance – recovered over a 7-year period through September 2018	12.9	-
Other	5.9	7.1
Entergy New Orleans Total	$178.8	$135.3

Entergy Texas

	2011	2010
	(In Millions)
Asset Retirement Obligation - recovery dependent upon timing of decommissioning (Note 9) (b)	$1.3	$1.4
Removal costs - recovered through depreciation rates (Note 9) (b)	4.5	7.3
Pension & postretirement costs (Note 11 – Qualified Pension Plans, Other Postretirement Benefits, and Non-Qualified Pension Plans) (b)	244.9	165.4
Provision for storm damages, including hurricane costs - recovered through securitization, insurance proceeds, and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators)	822.5	881.7
Transition to competition costs - recovered over a 15-year period through February 2021	89.2	95.8
Unamortized loss on reacquired debt - recovered over term of debt	10.8	12.7
Other	4.9	4.7
Entergy Texas Total	$1,178.1	$1,169.0

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Notes to Financial Statements

System Energy

	2011	2010
	(In Millions)
Asset Retirement Obligation - recovery dependent upon timing of decommissioning (Note 9) (b)	$59.6	$98.3
Removal costs - recovered through depreciation rates (Note 9) (b)	11.8	12.2
Pension & postretirement costs (Note 11 – Qualified Pension Plans and Other Postretirement Benefits) (b)	197.6	142.0
Sale-leaseback deferral (Note 10 – Sale and Leaseback Transactions – Grand Gulf Lease Obligations)	-	22.3
Unamortized loss on reacquired debt - recovered over term of debt	18.2	21.5
Other	0.6	0.4
System Energy Total	$287.8	$296.7

(a)

The jurisdictional split order assigned the regulatory asset to Entergy Texas. The regulatory asset, however, is being recovered and amortized at Entergy Gulf States Louisiana. As a result, a billing occurs monthly over the same term as the recovery and receipts will be submitted to Entergy Texas. Entergy Texas has recorded a receivable from Entergy Gulf States Louisiana and Entergy Gulf States Louisiana has recorded a corresponding payable.

(b)

Does not earn a return on investment, but is offset by related liabilities.

Fuel and purchased power cost recovery

Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2011 and 2010, that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review.

	2011	2010
	(In Millions)

Entergy Arkansas	$209.8	$61.5
Entergy Gulf States Louisiana (a)	$2.9	$77.8
Entergy Louisiana (a)	$1.5	$8.8
Entergy Mississippi	($15.8)	$3.2
Entergy New Orleans (a)	($7.5)	($2.8)
Entergy Texas	($64.7)	($77.4)

(a)

2011 and 2010 include $100.1 million for Entergy Gulf States Louisiana, $68 million for Entergy Louisiana, and $4.1 million for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be over a period greater than twelve months.

Entergy Arkansas

Production Cost Allocation Rider

The APSC approved a production cost allocation rider for recovery from customers of the retail portion of the costs allocated to Entergy Arkansas as a result of the System Agreement proceedings, which are discussed in the “System Agreement Cost Equalization Proceedings” section below. These costs cause an increase in Entergy Arkansas’s deferred fuel cost balance because Entergy Arkansas pays the costs over seven months but collects them from customers over twelve months.

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Notes to Financial Statements

Energy Cost Recovery Rider

Entergy Arkansas’s retail rates include an energy cost recovery rider to recover fuel and purchased energy costs in monthly bills. The rider utilizes prior calendar year energy costs and projected energy sales for the twelve-month period commencing on April 1 of each year to develop an energy cost rate, which is redetermined annually and includes a true-up adjustment reflecting the over-recovery or under-recovery, including carrying charges, of the energy cost for the prior calendar year. The energy cost recovery rider tariff also allows an interim rate request depending upon the level of over- or under-recovery of fuel and purchased energy costs.

In early October 2005, the APSC initiated an investigation into Entergy Arkansas's interim energy cost recovery rate. The investigation focused on Entergy Arkansas's 1) gas contracting, portfolio, and hedging practices; 2) wholesale purchases during the period; 3) management of the coal inventory at its coal generation plants; and 4) response to the contractual failure of the railroads to provide coal deliveries. In March 2006, the APSC extended its investigation to cover the costs included in Entergy Arkansas's March 2006 annual energy cost rate filing, and a hearing was held in the APSC energy cost recovery investigation in October 2006.

In January 2007 the APSC issued an order in its review of the energy cost rate. The APSC found that Entergy Arkansas failed to maintain an adequate coal inventory level going into the summer of 2005 and that Entergy Arkansas should be responsible for any incremental energy costs resulting from two outages caused by employee and contractor error. The coal plant generation curtailments were caused by railroad delivery problems and Entergy Arkansas has since resolved litigation with the railroad regarding the delivery problems. The APSC staff was directed to perform an analysis with Entergy Arkansas’s assistance to determine the additional fuel and purchased energy costs associated with these findings and file the analysis within 60 days of the order. After a final determination of the costs is made by the APSC, Entergy Arkansas would be directed to refund that amount with interest to its customers as a credit on the energy cost recovery rider. Entergy Arkansas requested rehearing of the order. In March 2007, in order to allow further consideration by the APSC, the APSC granted Entergy Arkansas’s petition for rehearing and for stay of the APSC order.

In October 2008 Entergy Arkansas filed a motion to lift the stay and to rescind the APSC's January 2007 order in light of the arguments advanced in Entergy Arkansas’s rehearing petition and because the value for Entergy Arkansas’s customers obtained through the resolved railroad litigation is significantly greater than the incremental cost of actions identified by the APSC as imprudent. In December 2008, the APSC denied the motion to lift the stay pending resolution of Entergy Arkansas’s rehearing request and the unresolved issues in the proceeding. The APSC ordered the parties to submit their unresolved issues list in the pending proceeding, which the parties did. In February 2010 the APSC denied Entergy Arkansas’s request for rehearing, and held a hearing in September 2010 to determine the amount of damages, if any, that should be assessed against Entergy Arkansas. A decision is pending. Entergy Arkansas expects the amount of damages, if any, to have an immaterial effect on its results of operations, financial position, or cash flows.

The APSC also established a separate docket to consider the resolved railroad litigation, and in February 2010 it established a procedural schedule that concluded with testimony through September 2010. Testimony has been filed and the APSC will decide the case based on the record in the proceeding, including the prefiled testimony.

Entergy Gulf States Louisiana and Entergy Louisiana

Entergy Gulf States Louisiana and Entergy Louisiana recover electric fuel and purchased power costs for the billing month based upon the level of such costs incurred two months prior to the billing month. Entergy Gulf States Louisiana’s purchased gas adjustments include estimates for the billing month adjusted by a surcharge or credit that arises from an annual reconciliation of fuel costs incurred with fuel cost revenues billed to customers, including carrying charges.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

In January 2003 the LPSC authorized its staff to initiate a proceeding to audit the fuel adjustment clause filings of Entergy Gulf States Louisiana and its affiliates. The audit included a review of the reasonableness of charges flowed by Entergy Gulf States Louisiana through its fuel adjustment clause for the period 1995 through 2004. Entergy Gulf States Louisiana and the LPSC Staff reached a settlement to resolve the audit that requires Entergy Gulf States Louisiana to refund $18 million to customers, including the realignment to base rates of $2 million of SO2 costs. The ALJ held a stipulation hearing and in November 2011 the LPSC issued an order approving the settlement. The refund was made in the November 2011 billing cycle. Entergy Gulf States Louisiana had previously recorded provisions for the estimated outcome of this proceeding.

In December 2011 the LPSC authorized its staff to initiate another proceeding to audit the fuel adjustment clause filings of Entergy Gulf States Louisiana and its affiliates. The audit includes a review of the reasonableness of charges flowed by Entergy Gulf States Louisiana through its fuel adjustment clause for the period 2005 through 2009.

In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana's fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009. Discovery is in progress, but a procedural schedule has not been established.

Entergy Mississippi

Entergy Mississippi’s rate schedules include an energy cost recovery rider that is adjusted quarterly to reflect accumulated over- or under-recoveries from the second prior quarter. Entergy Mississippi’s fuel cost recoveries are subject to annual audits conducted pursuant to the authority of the MPSC.

In July 2008 the MPSC began a proceeding to investigate the fuel procurement practices and fuel adjustment schedules of the Mississippi utility companies, including Entergy Mississippi. The MPSC stated that the goal of the proceeding is fact-finding so that the MPSC may decide whether to amend the current fuel cost recovery process. Hearings were held in July and August 2008. Further proceedings have not been scheduled.

Mississippi Attorney General Complaint

The Mississippi attorney general filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, Inc., and Entergy Power, Inc. alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. The litigation is wide ranging and relates to tariffs and procedures under which Entergy Mississippi purchases power not generated in Mississippi to meet electricity demand. Entergy believes the complaint is unfounded. On December 29, 2008, the defendant Entergy companies filed to remove the attorney general’s suit to U.S. District Court (the forum that Entergy believes is appropriate to resolve the types of federal issues raised in the suit), where it is currently pending, and additionally answered the complaint and filed a counter-claim for relief based upon the Mississippi Public Utilities Act and the Federal Power Act. The Mississippi attorney general has filed a pleading seeking to remand the matter to state court. In May 2009, the defendant Entergy companies filed a motion for judgment on the pleadings asserting grounds of federal preemption, the exclusive jurisdiction of the MPSC, and factual errors in the attorney general’s complaint.

In July 2011, the attorney general requested a status conference regarding its motion to remand. The court granted the attorney general’s request for a status conference, which was held in September 2011. Consistent with the court’s instructions, both parties submitted letters to the court in September 2011 providing updates on the facts of the case and the law, and the court has now taken the parties’ arguments under advisement.

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Notes to Financial Statements

Entergy New Orleans

Entergy New Orleans’s electric rate schedules include a fuel adjustment tariff designed to reflect no more than targeted fuel and purchased power costs, adjusted by a surcharge or credit for deferred fuel expense arising from the monthly reconciliation of actual fuel and purchased power costs incurred with fuel cost revenues billed to customers, including carrying charges.

Entergy Texas

Entergy Texas’s rate schedules include a fixed fuel factor to recover fuel and purchased power costs, including carrying charges, not recovered in base rates. Semi-annual revisions of the fixed fuel factor are made in March and September based on the market price of natural gas and changes in fuel mix. The amounts collected under Entergy Texas’s fixed fuel factor and any interim surcharge or refund are subject to fuel reconciliation proceedings before the PUCT.

In January 2008, Entergy Texas made a compliance filing with the PUCT describing how its 2007 rough production cost equalization receipts under the System Agreement were allocated between Entergy Gulf States, Inc.'s Texas and Louisiana jurisdictions. In December 2008 the PUCT adopted an ALJ proposal for decision recommending an additional $18.6 million allocation to Texas retail customers. Because the PUCT allocation to Texas retail customers is inconsistent with the LPSC allocation to Louisiana retail customers, the PUCT's decision resulted in trapped costs between the Texas and Louisiana jurisdictions with no mechanism for recovery. Entergy Texas filed with the FERC a proposed amendment to the System Agreement bandwidth formula to specifically calculate the payments to Entergy Gulf States Louisiana and Entergy Texas of Entergy Gulf States, Inc.'s rough production cost equalization receipts for 2007. In May 2009 the FERC issued an order rejecting the proposed amendment. Because of the FERC's order, Entergy Texas recorded the effects of the PUCT's allocation of the additional $18.6 million to Texas retail customers in the second quarter 2009. On an after-tax basis, the charge to earnings was approximately $13.0 million (including interest). The PUCT and FERC decisions are now final.

In May 2009, Entergy Texas filed with the PUCT a request to refund $46.1 million, including interest, of fuel cost recovery over-collections through February 2009. Pursuant to a stipulation among the various parties, in June 2009 the PUCT issued an order approving a refund of $59.2 million, including interest, of fuel cost recovery overcollections through March 2009. The refund was made for most customers over a three-month period beginning July 2009.

In October 2009, Entergy Texas filed with the PUCT a request to refund approximately $71 million, including interest, of fuel cost recovery over-collections through September 2009. Pursuant to a stipulation among the various parties, the PUCT issued an order approving a refund of $87.8 million, including interest, of fuel cost recovery overcollections through October 2009. The refund was made for most customers over a three-month period beginning January 2010.

In June 2010, Entergy Texas filed with the PUCT a request to refund approximately $66 million, including interest, of fuel cost recovery over-collections through May 2010. In September 2010 the PUCT issued an order providing for a $77 million refund, including interest, for fuel cost recovery over-collections through June 2010. The refund was made for most customers over a three-month period beginning with the September 2010 billing cycle.

In December 2010, Entergy Texas filed with the PUCT a request to refund fuel cost recovery over-collections through October 2010. Pursuant to a stipulation among the parties that was approved by the PUCT in March 2011, Entergy Texas refunded over-collections through November 2010 of approximately $73 million, including interest through the refund period. The refund was made for most customers over a three-month period that began with the February 2011 billing cycle.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

In December 2011, Entergy Texas filed with the PUCT a request to refund approximately $43 million, including interest, of fuel cost recovery over-collections through October 2011. Entergy Texas and the parties to the proceeding reached an agreement that Entergy Texas will refund $67 million, including interest, over a three-month period, which refund includes additional over-recoveries through December 2011. Entergy Texas and the parties requested that interim rates consistent with the settlement be approved effective with the March 2012 billing month, and this request was granted by the presiding ALJ on February 16, 2012.

Entergy Texas’s December 2009 rate case filing, which is discussed below, also included a request to reconcile $1.8 billion of fuel and purchased power costs covering the period April 2007 through June 2009.

Entergy Texas’s November 2011 rate case filing, which is discussed below, also includes a request to reconcile $1.3 billion of fuel and purchased power costs covering the period July 2009 through June 2011.

Retail Rate Proceedings

The following chart summarizes the Utility operating companies' current retail base rates:

Company	Authorized Return on Common Equity

Entergy Arkansas	10.2%	- Current retail base rates implemented in the July 2010 billing cycle pursuant to a settlement approved by the APSC.

Entergy Gulf States Louisiana	9.9%-11.4% Electric; 10.0%-11.0% Gas	- Current retail electric base rates implemented based on Entergy Gulf States Louisiana's 2010 test year formula rate plan filing approved by the LPSC. - Current retail gas base rates reflect the rate stabilization plan filing for the 2010 test year ended September 2010.

Entergy Louisiana	9.45%- 11.05%	- Current retail base rates based on Entergy Louisiana's 2010 test year formula rate plan filing approved by the LPSC.

Entergy Mississippi	10.54%- 12.72%	- Current retail base rates reflect Entergy Mississippi's latest formula rate plan filing, based on the 2010 test year, and a stipulation approved by the MPSC.

Entergy New Orleans	10.7% - 11.5% Electric; 10.25% - 11.25% Gas	- Current retail base rates reflect Entergy New Orleans's 2010 test year formula rate plan filing and a settlement approved by the City Council.

Entergy Texas	10.125%	- Current retail base rates reflect Entergy Texas's 2009 base rate case filing and a settlement approved by the PUCT.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Filings with the APSC (Entergy Arkansas)

Retail Rates

2009 Base Rate Filing

In September 2009, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs. In June 2010 the APSC approved a settlement and subsequent compliance tariffs that provide for a $63.7 million rate increase, effective for bills rendered for the first billing cycle of July 2010. The settlement provides for a 10.2% return on common equity.

Filings with the LPSC

Formula Rate Plans (Entergy Gulf States Louisiana and Entergy Louisiana)

In March 2005 the LPSC approved a settlement proposal to resolve various dockets covering a range of issues for Entergy Gulf States Louisiana and Entergy Louisiana. The settlement included the establishment of a three-year formula rate plan for Entergy Gulf States Louisiana that, among other provisions, established a return on common equity mid-point of 10.65% for the initial three-year term of the plan and permits Entergy Gulf States Louisiana to recover incremental capacity costs outside of a traditional base rate proceeding. Under the formula rate plan, over- and under-earnings outside an allowed range of 9.9% to 11.4% are allocated 60% to customers and 40% to Entergy Gulf States Louisiana. Entergy Gulf States Louisiana made its initial formula rate plan filing in June 2005. The formula rate plan was subsequently extended one year.

Entergy Louisiana made a rate filing with the LPSC requesting a base rate increase in January 2004. In May 2005 the LPSC approved a settlement that included the adoption of a three-year formula rate plan, the terms of which included an ROE mid-point of 10.25% for the initial three-year term of the plan and permit Entergy Louisiana to recover incremental capacity costs outside of a traditional base rate proceeding. Under the formula rate plan, over- and under-earnings outside an allowed regulatory range of 9.45% to 11.05% will be allocated 60% to customers and 40% to Entergy Louisiana. The initial formula rate plan filing was made in May 2006.

The formula rate plans for Entergy Gulf States Louisiana and Entergy Louisiana have subsequently been extended, with return on common equity provisions consistent with the previously approved provisions, to cover the 2008, 2009, 2010, and 2011 test years.

Retail Rates - Electric

(Entergy Gulf States Louisiana)

In October 2009 the LPSC approved a settlement that resolved Entergy Gulf States Louisiana’s 2007 test year filing and provided for a formula rate plan for the 2008, 2009, and 2010 test years. 10.65% is the target midpoint return on equity for the formula rate plan, with an earnings bandwidth of +/- 75 basis points (9.90% - 11.40%). Entergy Gulf States Louisiana, effective with the November 2009 billing cycle, reset its rates to achieve a 10.65% return on equity for the 2008 test year. The rate reset, a $44.3 million increase that includes a $36.9 million cost of service adjustment, plus $7.4 million net for increased capacity costs and a base rate reclassification, was implemented for the November 2009 billing cycle, and the rate reset was subject to refund pending review of the 2008 test year filing that was made in October 2009. In January 2010, Entergy Gulf States Louisiana implemented an additional $23.9 million rate increase pursuant to a special rate implementation filing made in December 2009, primarily for incremental capacity costs approved by the LPSC. In May 2010, Entergy Gulf States Louisiana and the LPSC staff submitted a joint report on the 2008 test year filing and requested that the LPSC accept the report, which resulted in a $0.8 million reduction in rates effective in the June 2010 billing cycle and a $0.5 million refund. At its May 19, 2010 meeting, the LPSC accepted the joint report.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

In May 2010, Entergy Gulf States Louisiana made its formula rate plan filing with the LPSC for the 2009 test year. The filing reflected a 10.25% return on common equity, which is within the allowed earnings bandwidth, indicating no cost of service rate change is necessary under the formula rate plan. The filing does reflect, however, a revenue requirement increase to provide supplemental funding for the decommissioning trust maintained for the LPSC-regulated 70% share of River Bend, in response to a NRC notification of a projected shortfall of decommissioning funding assurance. The filing also reflected a rate increase for incremental capacity costs. In July 2010 the LPSC approved a $7.8 million increase in the revenue requirement for decommissioning, effective September 2010. In August 2010, Entergy Gulf States Louisiana made a revised 2009 test year filing. The revised filing reflected a 10.12% earned return on common equity, which is within the allowed earnings bandwidth resulting in no cost of service adjustment. The revised filing also reflected two increases outside of the formula rate plan sharing mechanism: (1) the previously approved decommissioning revenue requirement, and (2) $25.2 million for capacity costs. The rates reflected in the revised filing became effective, beginning with the first billing cycle of September 2010. Entergy Gulf States Louisiana and the LPSC staff subsequently submitted a joint report on the 2009 test year filing consistent with these terms and the LPSC approved the joint report in January 2011.

In May 2011, Entergy Gulf States Louisiana made a special formula rate plan rate implementation filing with the LPSC that implements effective with the May 2011 billing cycle a $5.1 million rate decrease to reflect adjustments in accordance with a previous LPSC order relating to the acquisition of Unit 2 of the Acadia Energy Center by Entergy Louisiana. As a result of the closing of the acquisition and termination of the pre-acquisition power purchase agreement with Acadia, Entergy Gulf States Louisiana’s allocation of capacity related to this unit ended, resulting in a reduction in the additional capacity revenue requirement.

In May 2011, Entergy Gulf States Louisiana made its formula rate plan filing with the LPSC for the 2010 test year. The filing reflects an 11.11% earned return on common equity, which is within the allowed earnings bandwidth, indicating no cost of service rate change is necessary under the formula rate plan. The filing also reflects a $22.8 million rate decrease for incremental capacity costs. Entergy Gulf States Louisiana and the LPSC Staff subsequently filed a joint report that also stated that no cost of service rate change is necessary under the formula rate plan, and the LPSC approved it in October 2011.

In November 2011 the LPSC approved a one-year extension of Entergy Gulf States Louisiana’s formula rate plan. In addition, Entergy Gulf States Louisiana is required to file a full rate case by January 2013, if the LPSC has not acted to deny the requested transmission change-of-control to the MISO RTO. If the LPSC has denied this request, then the rate case must be filed by September 30, 2012.

(Entergy Louisiana)

In October 2009 the LPSC approved a settlement that resolved Entergy Louisiana’s 2006 and 2007 test year filings and provided for a new formula rate plan for the 2008, 2009, and 2010 test years. 10.25% is the target midpoint return on equity for the formula rate plan, with an earnings bandwidth of +/- 80 basis points (9.45% - 11.05%).

Entergy Louisiana was permitted, effective with the November 2009 billing cycle, to reset its rates to achieve a 10.25% return on equity for the 2008 test year. The rate reset, a $2.5 million increase that included a $16.3 million cost of service adjustment less a $13.8 million net reduction for decreased capacity costs and a base rate reclassification, was implemented for the November 2009 billing cycle, and the rate reset was subject to refund pending review of the 2008 test year filing that was made in October 2009. In April 2010, Entergy Louisiana and the LPSC staff submitted a joint report on the 2008 test year filing and requested that the LPSC accept the report, which resulted in a $0.1 million reduction in rates effective in the May 2010 billing cycle and a $0.1 million refund. In addition, Entergy Louisiana moved the recovery of approximately $12.5 million of capacity costs from fuel adjustment clause recovery to base rate recovery. At its April 21, 2010 meeting, the LPSC accepted the joint report.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

In May 2010, Entergy Louisiana made its formula rate plan filing with the LPSC for the 2009 test year. The filing reflected a 10.82% return on common equity, which is within the allowed earnings bandwidth, indicating no cost of service rate change is necessary under the formula rate plan. The filing does reflect, however, a revenue requirement increase to provide supplemental funding for the decommissioning trust maintained for Waterford 3, in response to a NRC notification of a projected shortfall of decommissioning funding assurance. The filing also reflected a rate change for incremental capacity costs. In July 2010 the LPSC approved a $3.5 million increase in the retail revenue requirement for decommissioning, effective September 2010. In August 2010, Entergy Louisiana made a revised 2009 test year formula rate plan filing. The revised filing reflected a 10.82% earned return on common equity, which is within the allowed earnings bandwidth resulting in no cost of service adjustment. The filing also reflected two increases outside of the formula rate plan sharing mechanism: (1) the previously approved decommissioning revenue requirement, and (2) $2.2 million for capacity costs. The rates reflected in the revised filing became effective beginning with the first billing cycle of September 2010. Entergy Louisiana and the LPSC staff subsequently submitted a joint report on the 2009 test year filing consistent with these terms and the LPSC approved the joint report in December 2010.

In May 2011, Entergy Louisiana made a special formula rate plan rate implementation filing with the LPSC that implements effective with the May 2011 billing cycle a $43.1 million net rate increase to reflect adjustments in accordance with a previous LPSC order relating to the acquisition of Unit 2 of the Acadia Energy Center. The net rate increase represents the decrease in the additional capacity revenue requirement resulting from the termination of the power purchase agreement with Acadia and the increase in the revenue requirement resulting from the ownership of the Acadia facility. In August 2011, Entergy Louisiana made a filing to correct the May 2011 filing and decrease the rate by $1.1 million.

In May 2011, Entergy Louisiana made its formula rate plan filing with the LPSC for the 2010 test year. The filing reflects an 11.07% earned return on common equity, which is just outside of the allowed earnings bandwidth and results in no cost of service rate change under the formula rate plan. The filing also reflects a very slight ($9 thousand) rate increase for incremental capacity costs. Entergy Louisiana and the LPSC Staff subsequently filed a joint report that reflects an 11.07% earned return and results in no cost of service rate change under the formula rate plan, and the LPSC approved the joint report in October 2011.

In November 2011 the LPSC approved a one-year extension of Entergy Louisiana’s current formula rate plan. The next formula rate plan filing, for the 2011 test year, will be made in May 2012 and will include a separate identification of any operating and maintenance expense savings that are expected to occur once the Waterford 3 steam generator replacement project is complete. Pursuant to the LPSC decision, from September 2012 through December 2012 earnings above an 11.05% return on common equity (based on the 2011 test year) would be accrued and used to offset the Waterford 3 replacement steam generator revenue requirement for the first twelve months that the unit is in rates. If the project is not in service by January 1, 2013, earnings above a 10.25% return on common equity (based on the 2011 test year) for the period January 1, 2013 through the date that the project is placed in service will be accrued and used to offset the incremental revenue requirement for the first twelve months that the unit is in rates. Upon the in-service date of the replacement steam generators, rates will increase, subject to refund following any prudence review, by the full revenue requirement associated with the replacement steam generators, less (i) the previously accrued excess earnings from September 2012 until the in-service date and (ii) any earnings above a 10.25% return on common equity (based on the 2011 test year) for the period following the in-service date, provided that the excess earnings accrued prior to the in-service date shall only offset the revenue requirement for the first year of operation of the replacement steam generators. These rates are anticipated to remain in effect until Entergy Louisiana’s next full rate case is resolved. Entergy Louisiana is required to file a full rate case by January 2013, if the LPSC has not acted to deny the requested transmission change-of-control to the MISO RTO. If the LPSC has denied this request, then the rate case must be filed by September 30, 2012.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Retail Rates - Gas (Entergy Gulf States Louisiana)

In January 2012, Entergy Gulf States Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2011. The filing showed an earned return on common equity of 10.48%, which is within the earnings bandwidth of 10.5%, plus or minus fifty basis points. The sixty-day review and comment period for this filing remains open.

In January 2011, Entergy Gulf States Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2010. The filing showed an earned return on common equity of 8.84% and a revenue deficiency of $0.3 million. In March 2011 the LPSC Staff filed its findings, suggesting an adjustment that produced an 11.76% earned return on common equity for the test year and a $0.2 million rate reduction. Entergy Gulf States Louisiana implemented the $0.2 million rate reduction effective with the May 2011 billing cycle. The LPSC docket is now closed.

In January 2010, Entergy Gulf States Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2009. The filing showed an earned return on common equity of 10.87%, which is within the earnings bandwidth of 10.5% plus or minus fifty basis points, resulting in no rate change. In April 2010, Entergy Gulf States Louisiana filed a revised evaluation report reflecting changes agreed upon with the LPSC Staff. The revised evaluation report also resulted in no rate change.

Filings with the MPSC (Entergy Mississippi)

Formula Rate Plan Filings

In September 2009, Entergy Mississippi filed with the MPSC proposed modifications to its formula rate plan rider. In March 2010 the MPSC issued an order: (1) providing the opportunity for a reset of Entergy Mississippi's return on common equity to a point within the formula rate plan bandwidth and eliminating the 50/50 sharing that had been in the plan, (2) modifying the performance measurement process, and (3) replacing the revenue change limit of two percent of revenues, which was subject to a $14.5 million revenue adjustment cap, with a limit of four percent of revenues, although any adjustment above two percent requires a hearing before the MPSC. The MPSC did not approve Entergy Mississippi's request to use a projected test year for its annual scheduled formula rate plan filing and, therefore, Entergy Mississippi will continue to use a historical test year for its annual evaluation reports under the plan.

In March 2010, Entergy Mississippi submitted its 2009 test year filing, its first annual filing under the new formula rate plan rider. In June 2010 the MPSC approved a joint stipulation between Entergy Mississippi and the Mississippi Public Utilities Staff that provides for no change in rates, but does provide for the deferral as a regulatory asset of $3.9 million of legal expenses associated with certain litigation involving the Mississippi Attorney General, as well as ongoing legal expenses in that litigation until the litigation is resolved.

In March 2011, Entergy Mississippi submitted its formula rate plan 2010 test year filing. The filing shows an earned return on common equity of 10.65% for the test year, which is within the earnings bandwidth and results in no change in rates. In November 2011 the MPSC approved a joint stipulation between Entergy Mississippi and the Mississippi Public Utilities Staff that provides for no change in rates.

Filings with the City Council (Entergy New Orleans)

Formula Rate Plan

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

cost recovery from fuel to electric base rates, and a $4.95 million gas base rate increase, both effective June 1, 2009, with adjustment of the customer charges for all rate classes. A new three-year formula rate plan was also adopted, with terms including an 11.1% benchmark electric return on common equity (ROE) with a +/- 40 basis point bandwidth and a 10.75% benchmark gas ROE with a +/- 50 basis point bandwidth. Earnings outside the bandwidth reset to the midpoint benchmark ROE, with rates changing on a prospective basis depending on whether Entergy New Orleans is over- or under-earning. The formula rate plan also includes a recovery mechanism for City Council-approved capacity additions, plus provisions for extraordinary cost changes and force majeure events.

In May 2010, Entergy New Orleans filed its electric and gas formula rate plan evaluation reports. The filings requested a $12.8 million electric base revenue decrease and a $2.4 million gas base revenue increase. Entergy New Orleans and the City Council's Advisors reached a settlement that resulted in an $18.0 million electric base revenue decrease and zero gas base revenue change effective with the October 2010 billing cycle. The City Council approved the settlement in November 2010.

In May 2011, Entergy New Orleans filed its electric and gas formula rate plan evaluation reports for the 2010 test year. The filings requested a $6.5 million electric rate decrease and a $1.1 million gas rate decrease. Entergy New Orleans and the City Council’s Advisors reached a settlement that results in an $8.5 million incremental electric rate decrease and a $1.6 million gas rate decrease. The settlement also provides for the deferral of $13.4 million of Michoud plant maintenance expenses incurred in 2010 and the establishment of a regulatory asset that will be amortized over the period October 2011 through September 2018. The City Council approved the settlement in September 2011. The new rates were effective with the first billing cycle of October 2011.

The 2008 rate case settlement also included $3.1 million per year in electric rates to fund the Energy Smart energy efficiency programs. In September 2009 the City Council approved the energy efficiency programs filed by Entergy New Orleans. The rate settlement provides an incentive for Entergy New Orleans to meet or exceed energy savings targets set by the City Council and provides a mechanism for Entergy New Orleans to recover lost contribution to fixed costs associated with the energy savings generated from the energy efficiency programs.

Filings with the PUCT and Texas Cities (Entergy Texas)

Retail Rates

2009 Rate Case

In December 2009, Entergy Texas filed a rate case requesting a $198.7 million increase reflecting an 11.5% return on common equity based on an adjusted June 2009 test year. The rate case also includes a $2.8 million revenue requirement to provide supplemental funding for the decommissioning trust maintained for the 70% share of River Bend for which Entergy Texas retail customers are partially responsible, in response to an NRC notification of a projected shortfall of decommissioning funding assurance. Beginning in May 2010, Entergy Texas implemented a $17.5 million interim rate increase, subject to refund. Intervenors and PUCT Staff filed testimony recommending adjustments that would result in a maximum rate increase, based on the PUCT Staff’s testimony, of $58 million.

The parties filed a settlement in August 2010 intended to resolve the rate case proceeding. The settlement provides for a $59 million base rate increase for electricity usage beginning August 15, 2010, with an additional increase of $9 million for bills rendered beginning May 2, 2011. The settlement stipulates an authorized return on equity of 10.125%. The settlement states that Entergy Texas's fuel costs for the period April 2007 through June 2009 are reconciled, with $3.25 million of disallowed costs, which were included in an interim fuel refund. The settlement also sets River Bend decommissioning costs at $2.0 million annually. Consistent with the settlement, in the third quarter 2010, Entergy Texas amortized $11 million of rate case costs. The PUCT approved the settlement in December 2010.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

2011 Rate Case

In November 2011, Entergy Texas filed a rate case requesting a $112 million base rate increase reflecting a 10.6% return on common equity based on an adjusted June 2011 test year. The rate case also proposed a purchased power recovery rider. The parties have agreed to a procedural schedule that contemplates a final decision by July 30, 2012, with rates relating back to June 30, 2012. On January 12, 2012, the PUCT voted not to address the purchased power recovery rider in the current rate case, but the PUCT voted to set a baseline in the rate case proceeding that would be applicable if a purchased power capacity rider is approved in a separate proceeding.

System Agreement Cost Equalization Proceedings

In June 2005, the FERC issued a decision in System Agreement litigation that had been commenced by the LPSC, and essentially affirmed its decision in a December 2005 order on rehearing. The FERC decision concluded, among other things, that:

·	The System Agreement no longer roughly equalizes total production costs among the Utility operating companies.

·	In order to reach rough production cost equalization, the FERC imposed a bandwidth remedy by which each company’s total annual production costs will have to be within +/- 11% of Entergy System average total annual production costs.

In calculating the production costs for this purpose under the FERC’s order, output from the Vidalia hydroelectric power plant will not reflect the actual Vidalia price for the year but is priced at that year’s average price paid by Entergy Louisiana for the exchange of electric energy under Service Schedule MSS-3 of the System Agreement, thereby reducing the amount of Vidalia costs reflected in the comparison of the Utility operating companies’ total production costs.

·	The remedy ordered by FERC in 2005 required no refunds and became effective based on calendar year 2006 production costs and the first reallocation payments were made in 2007.

The FERC’s decision reallocates total production costs of the Utility operating companies whose relative total production costs expressed as a percentage of Entergy System average production costs are outside an upper or lower bandwidth. Under the current circumstances, this will be accomplished by payments from Utility operating companies whose production costs are more than 11% below Entergy System average production costs to Utility operating companies whose production costs are more than the Entergy System average production cost, with payments going first to those Utility operating companies whose total production costs are farthest above the Entergy System average.

Assessing the potential effects of the FERC’s decision requires assumptions regarding the future total production cost of each Utility operating company, which assumptions include the mix of solid fuel and gas-fired generation available to each company and the costs of natural gas and purchased power. Entergy Louisiana, Entergy Gulf States Louisiana, Entergy Texas, and Entergy Mississippi are more dependent upon gas-fired generation sources than Entergy Arkansas or Entergy New Orleans. Of these, Entergy Arkansas is the least dependent upon gas-fired generation sources. Therefore, increases in natural gas prices likely will increase the amount by which Entergy Arkansas’s total production costs are below the Entergy System average production costs.

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Notes to Financial Statements

The LPSC, APSC, MPSC, and the Arkansas Electric Energy Consumers appealed the FERC’s decision to the United States Court of Appeals for the D.C. Circuit. Entergy and the City of New Orleans intervened in the various appeals. The D.C. Circuit issued its decision in April 2008. The D.C. Circuit concluded that the FERC’s orders had failed to adequately explain both its conclusion that it was prohibited from ordering refunds for the 20-month period from September 13, 2001 - May 2, 2003 and its determination to implement the bandwidth remedy commencing on January 1, 2006, rather than June 1, 2005. The D.C. Circuit remanded the case to FERC for further proceedings on these issues.

On October 20, 2011, the FERC issued an order addressing the D.C. Circuit remand on these two issues. On the first issue, the FERC concluded that it did have the authority to order refunds, but decided that it would exercise its equitable discretion and not require refunds for the 20-month period from September 13, 2001 - May 2, 2003. Because the ruling on refunds relied on findings in the interruptible load proceeding that is discussed below, the FERC concluded that the refund ruling will be held in abeyance pending the outcome of the rehearing requests in that proceeding. On the second issue, the FERC reversed its prior decision and ordered that the prospective bandwidth remedy begin on June 1, 2005 (the date of its initial order in the proceeding) rather than January 1, 2006, as it had previously ordered. Pursuant to the October 20, 2011 order, Entergy was required to calculate the additional bandwidth payments for the period June - December 2005 utilizing the bandwidth formula tariff prescribed by the FERC that was filed in a December 2006 compliance filing and accepted by the FERC in an April 2007 order. As is the case with bandwidth remedy payments, these payments and receipts will ultimately be paid by Utility operating company customers to other Utility operating company customers.

In December 2011, Entergy filed with the FERC its compliance filing that provides the payments and receipts among the Utility operating companies pursuant to the FERC’s October 2011 order. The filing shows the following payments/receipts among the Utility operating companies:

	Payments or (Receipts)
	(In Millions)
Entergy Arkansas	$156
Entergy Gulf States Louisiana	($75)
Entergy Louisiana	$-
Entergy Mississippi	($33)
Entergy New Orleans	($5)
Entergy Texas	($43)

Entergy Arkansas made its payment in January 2012. In February 2012, Entergy Arkansas filed for an interim adjustment to its production cost allocation rider requesting that the $156 million payment be collected from customers over the 22-month period from March 2012 through December 2013. On February 27, 2012, the APSC staff responded to Entergy Arkansas’s filing and requested that the APSC: 1) determine whether Entergy Arkansas must make a request separate from the production cost allocation rider to ask for recovery of the payment and 2) find that Arkansas law does not allow retroactive ratemaking and not permit recovery of the payment from customers through the production cost allocation rider. In the alternative the APSC staff requested that the APSC determine that an interim production cost allocation rider rate does not become effective without an APSC order.

The LPSC and the APSC have requested rehearing of the FERC’s October 2011 order. The APSC, LPSC, the PUCT, and other parties intervened in the December 2011 compliance filing proceeding, and the APSC and the LPSC also filed protests.

Calendar Year 2011 Production Costs

The liabilities and assets for the preliminary estimate of the payments and receipts required to implement the FERC’s remedy based on calendar year 2011 production costs were recorded in December 2011, based on certain year-to-date information. The preliminary estimate was recorded based on the following estimate of the payments/receipts among the Utility operating companies for 2012.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

	Payments or (Receipts)
	(In Millions)

Entergy Arkansas	$37
Entergy Gulf States Louisiana	$-
Entergy Louisiana	($37)
Entergy Mississippi	$-
Entergy New Orleans	$-
Entergy Texas	$-

The actual payments/receipts for 2012, based on calendar year 2011 production costs, will not be calculated until the Utility operating companies’ FERC Form 1s have been filed. Once the calculation is completed, it will be filed at the FERC. The level of any payments and receipts is significantly affected by a number of factors, including, among others, weather, the price of alternative fuels, the operating characteristics of the Entergy System generating fleet, and multiple factors affecting the calculation of the non-fuel related revenue requirement components of the total production costs, such as plant investment.

2011 Rate Filing Based on Calendar Year 2010 Production Costs

In May 2011, Entergy filed with the FERC the 2011 rates in accordance with the FERC’s orders in the System Agreement proceeding. The filing shows the following payments/receipts among the Utility operating companies for 2011, based on calendar year 2010 production costs, commencing for service in June 2011, are necessary to achieve rough production cost equalization under the FERC’s orders:

	Payments or (Receipts)
	(In Millions)
Entergy Arkansas	$77
Entergy Gulf States Louisiana	($12)
Entergy Louisiana	$-
Entergy Mississippi	($40)
Entergy New Orleans	($25)
Entergy Texas	$-

Several parties intervened in the proceeding at the FERC, including the LPSC, which filed a protest as well. In July 2011, the FERC accepted Entergy's proposed rates for filing, effective June 1, 2011, subject to refund, set the proceeding for hearing procedures, and then held those procedures in abeyance pending FERC decisions in the prior production cost proceedings currently before the FERC on review.

Prior Years’ Rough Production Cost Equalization Rates

Each May since 2007 Entergy has filed with the FERC the rates to implement the FERC’s orders in the System Agreement proceeding. These filings show the following payments/receipts among the Utility operating companies are necessary to achieve rough production cost equalization as defined by the FERC’s orders:

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Notes to Financial Statements

	2007 Payments or (Receipts) Based on 2006 Costs	2008 Payments or (Receipts) Based on 2007 Costs	2009 Payments or (Receipts) Based on 2008 Costs	2010 Payments or (Receipts) Based on 2009 Costs
	(In Millions)

Entergy Arkansas	$252	$252	$390	$41
Entergy Gulf States Louisiana	($120)	($124)	($107)	$-
Entergy Louisiana	($91)	($36)	($140)	($22)
Entergy Mississippi	($41)	($20)	($24)	($19)
Entergy New Orleans	$-	($7)	$-	$-
Entergy Texas	($30)	($65)	($119)	$-

The APSC has approved a production cost allocation rider for recovery from customers of the retail portion of the costs allocated to Entergy Arkansas. Management believes that any changes in the allocation of production costs resulting from the FERC’s decision and related retail proceedings should result in similar rate changes for retail customers, subject to specific circumstances that have caused trapped costs. See “Fuel and purchased power cost recovery, Entergy Texas,” above for discussion of a PUCT decision that resulted in $18.6 million of trapped costs between Entergy’s Texas and Louisiana jurisdictions. See “2007 Rate Filing Based on Calendar Year 2006 Production Costs” below for a discussion of a FERC decision that could result in $14.5 million of trapped costs at Entergy Arkansas.

Based on the FERC’s April 27, 2007 order on rehearing that is discussed above, in the second quarter 2007 Entergy Arkansas recorded accounts payable and Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, and Entergy Texas recorded accounts receivable to reflect the rough production cost equalization payments and receipts required to implement the FERC’s remedy based on calendar year 2006 production costs. Entergy Arkansas recorded a corresponding regulatory asset for its right to collect the payments from its customers, and Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, and Entergy Texas recorded corresponding regulatory liabilities for their obligations to pass the receipts on to their customers. The companies have followed this same accounting practice each year since then. The regulatory asset and liabilities are shown as “System Agreement cost equalization” on the respective balance sheets.

2007 Rate Filing Based on Calendar Year 2006 Production Costs

Several parties intervened in the 2007 rate proceeding at the FERC, including the APSC, the MPSC, the Council, and the LPSC, which have also filed protests. The PUCT also intervened. Intervenor testimony was filed in which the intervenors and also the FERC Staff advocated a number of positions on issues that affect the level of production costs the individual Utility operating companies are permitted to reflect in the bandwidth calculation, including the level of depreciation and decommissioning expense for nuclear facilities. The effect of the various positions would be to reallocate costs among the Utility operating companies. The Utility operating companies filed rebuttal testimony explaining why the bandwidth payments are properly recoverable under the AmerenUE contract, and explaining why the positions of FERC Staff and intervenors on the other issues should be rejected. A hearing in this proceeding concluded in July 2008, and the ALJ issued an initial decision in September 2008. The ALJ’s initial decision concluded, among other things, that: (1) the decisions to not exercise Entergy Arkansas’s option to purchase the Independence plant in 1996 and 1997 were prudent; (2) Entergy Arkansas properly flowed a portion of the bandwidth payments through to AmerenUE in accordance with the wholesale power contract; and (3) the level of nuclear depreciation and decommissioning expense reflected in the bandwidth calculation should be calculated based on NRC-authorized license life, rather than the nuclear depreciation and decommissioning expense authorized by the retail regulators for purposes of retail ratemaking. Following briefing by the parties, the matter was submitted to the FERC for decision. On January 11, 2010, the FERC issued its decision both affirming and overturning certain

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Notes to Financial Statements

of the ALJ’s rulings, including overturning the decision on nuclear depreciation and decommissioning expense. The FERC’s conclusion related to the AmerenUE contract does not permit Entergy Arkansas to recover a portion of its bandwidth payment from AmerenUE. The Utility operating companies requested rehearing of that portion of the decision and requested clarification on certain other portions of the decision.

AmerenUE argued that its current wholesale power contract with Entergy Arkansas, pursuant to which Entergy Arkansas sells power to AmerenUE, does not permit Entergy Arkansas to flow through to AmerenUE any portion of Entergy Arkansas’s bandwidth payment. According to AmerenUE, Entergy Arkansas has sought to collect from AmerenUE approximately $14.5 million of the 2007 Entergy Arkansas bandwidth payment. The AmerenUE contract expired in August 2009. In April 2008, AmerenUE filed a complaint with the FERC seeking refunds of this amount, plus interest, in the event the FERC ultimately determines that bandwidth payments are not properly recovered under the AmerenUE contract. In response to the FERC’s decision discussed in the previous paragraph, Entergy Arkansas recorded a regulatory provision in the fourth quarter 2009 for a potential refund to AmerenUE.

2008 Rate Filing Based on Calendar Year 2007 Production Costs

Several parties intervened in the 2008 rate proceeding at the FERC, including the APSC, the LPSC, and AmerenUE, which have also filed protests. Several other parties, including the MPSC and the City Council, have intervened in the proceeding without filing a protest. In direct testimony filed on January 9, 2009, certain intervenors and also the FERC staff advocated a number of positions on issues that affect the level of production costs the individual Utility operating companies are permitted to reflect in the bandwidth calculation, including the level of depreciation and decommissioning expense for the nuclear and fossil-fueled generating facilities. The effect of these various positions would be to reallocate costs among the Utility operating companies. In addition, three issues were raised alleging imprudence by the Utility operating companies, including whether the Utility operating companies had properly reflected generating units’ minimum operating levels for purposes of making unit commitment and dispatch decisions, whether Entergy Arkansas’s sales to third parties from its retained share of the Grand Gulf nuclear facility were reasonable, prudent, and non-discriminatory, and whether Entergy Louisiana’s long-term Evangeline gas purchase contract was prudent and reasonable.

The parties reached a partial settlement agreement of certain of the issues initially raised in this proceeding. The partial settlement agreement was conditioned on the FERC accepting the agreement without modification or condition, which the FERC did on August 24, 2009. A hearing on the remaining issues in the proceeding was completed in June 2009, and in September 2009 the ALJ issued an initial decision. The initial decision affirms Entergy’s position in the filing, except for two issues that may result in a reallocation of costs among the Utility operating companies. In October 2011 the FERC issued an order on the ALJ’s initial decision. The FERC’s order resulted in a minor reallocation of payments/receipts among the Utility operating companies on one issue in the 2008 rate filing. Entergy made a compliance filing in December 2011 showing the updated payment/receipt amounts. The LPSC filed a protest in response to the compliance filing.

2009 Rate Filing Based on Calendar Year 2008 Production Costs

Several parties intervened in the 2009 rate proceeding at the FERC, including the LPSC and Ameren, which have also filed protests. In July 2009 the FERC accepted Entergy's proposed rates for filing, effective June 1, 2009, subject to refund, and set the proceeding for hearing and settlement procedures. Settlement procedures were terminated and a hearing before the ALJ was held in April 2010. In August 2010 the ALJ issued an initial decision. The initial decision substantially affirms Entergy's position in the filing, except for one issue that may result in some reallocation of costs among the Utility operating companies. The LPSC, the FERC trial staff, and Entergy have submitted briefs on exceptions in the proceeding.

2010 Rate Filing Based on Calendar Year 2009 Production Costs

In May 2010, Entergy filed with the FERC the 2010 rates in accordance with the FERC’s orders in the System Agreement proceeding, and supplemented the filing in September 2010. Several parties intervened in the proceeding at the FERC, including the LPSC and the City Council, which have also filed protests. In July 2010 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2010, subject to refund, and set the proceeding for

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

hearing and settlement procedures. Settlement procedures have been terminated, and the ALJ scheduled hearings to begin in March 2011. Subsequently, in January 2011 the ALJ issued an order directing the parties and FERC Staff to show cause why this proceeding should not be stayed pending the issuance of FERC decisions in the prior production cost proceedings currently before the FERC on review. In March 2011 the ALJ issued an order placing this proceeding in abeyance.

Interruptible Load Proceeding

In April 2007 the U.S. Court of Appeals for the D.C. Circuit issued its opinion in the LPSC’s appeal of the FERC’s March 2004 and April 2005 orders related to the treatment under the System Agreement of the Utility operating companies’ interruptible loads. In its opinion, the D.C. Circuit concluded that the FERC (1) acted arbitrarily and capriciously by allowing the Utility operating companies to phase-in the effects of the elimination of the interruptible load over a 12-month period of time; (2) failed to adequately explain why refunds could not be ordered under Section 206(c) of the Federal Power Act; and (3) exercised appropriately its discretion to defer addressing the cost of sulfur dioxide allowances until a later time. The D.C. Circuit remanded the matter to the FERC for a more considered determination on the issue of refunds. The FERC issued its order on remand in September 2007, in which it directed Entergy to make a compliance filing removing all interruptible load from the computation of peak load responsibility commencing April 1, 2004 and to issue any necessary refunds to reflect this change. In addition, the order directed the Utility operating companies to make refunds for the period May 1995 through July 1996. In November 2007 the Utility operating companies filed a refund report describing the refunds to be issued pursuant to the FERC's orders. The LPSC filed a protest to the refund report in December 2007, and the Utility operating companies filed an answer to the protest in January 2008. The refunds were made in October 2008 by the Utility operating companies that owed refunds to the Utility operating companies that were due a refund under the decision. The APSC and the Utility operating companies appealed the FERC decisions to the D.C. Circuit. Because of its refund obligation to its customers as a result of this proceeding and a related LPSC proceeding, Entergy Louisiana recorded provisions during 2008 of approximately $16 million, including interest, for rate refunds. The refunds were made in the fourth quarter 2009.

Following the filing of petitioners' initial briefs, the FERC filed a motion requesting the D.C. Circuit hold the appeal of the FERC’s decisions ordering refunds in the interruptible load proceeding in abeyance and remand the record to the FERC. The D.C. Circuit granted the FERC’s unopposed motion in June 2009. In December 2009 the FERC established a paper hearing to determine whether the FERC had the authority and, if so, whether it would be appropriate to order refunds resulting from changes in the treatment of interruptible load in the allocation of capacity costs by the Utility operating companies. In August 2010 the FERC issued an order stating that it has the authority and refunds are appropriate. The APSC, MPSC, and Entergy requested rehearing of the FERC’s decision. In June 2011 the FERC issued an order granting rehearing in part and denying rehearing in part, in which the FERC determined to invoke its discretion to deny refunds. The FERC held that in this case where “the Entergy system as a whole collected the proper level of revenue, but, as was later established, incorrectly allocated peak load responsibility among the various Entergy operating companies….the Commission will apply here our usual practice in such cases, invoking our equitable discretion to not order refunds, notwithstanding our authority to do so.” The LPSC has requested rehearing of the FERC’s June 2011 decision. On October 6, 2011 the FERC issued an “Order Establishing Paper Hearing” inviting parties that oppose refunds to file briefs within 30 days addressing the LPSC’s argument that FERC precedent supports refunds under the circumstances present in this proceeding. Parties that favor refunds were then invited to file reply briefs within 21 days of the date that the initial briefs are due. Briefs were submitted and the matter is pending.

In September 2010 the FERC had issued an order setting the refund report filed in the proceeding in November 2007 for hearing and settlement judge procedures. In May 2011, Entergy filed a settlement agreement that resolved all issues relating to the refund report set for hearing. In June 2011 the settlement judge certified the settlement as uncontested and the settlement agreement is currently pending before the FERC. In July 2011, Entergy filed an amended/corrected refund report and a motion to defer action on the settlement agreement until after the FERC rules on the LPSC’s rehearing request regarding the June 2011 decision denying refunds.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Prior to the FERC’s June 2011 order on rehearing, Entergy Arkansas filed an application in November 2010 with the APSC for recovery of the refund that it paid. The APSC denied Entergy Arkansas’s application, and also denied Entergy Arkansas’s petition for rehearing. If the FERC were to order Entergy Arkansas to pay refunds on rehearing in the interruptible load proceeding the APSC’s decision would trap FERC-approved costs at Entergy Arkansas with no regulatory-approved mechanism to recover them. In August 2011, Entergy Arkansas filed a complaint in the United States District Court for the Eastern District of Arkansas asking for a declaratory judgment. In the complaint Entergy Arkansas asks the court to declare that the rejection of Entergy Arkansas’s application by the APSC is preempted by the Federal Power Act. The APSC filed a motion to dismiss the complaint. A trial in the proceeding is scheduled for July 2012.

Entergy Arkansas Opportunity Sales Proceeding

In June 2009, the LPSC filed a complaint requesting that the FERC determine that certain of Entergy Arkansas’s sales of electric energy to third parties: (a) violated the provisions of the System Agreement that allocate the energy generated by Entergy System resources, (b) imprudently denied the Entergy System and its ultimate consumers the benefits of low-cost Entergy System generating capacity, and (c) violated the provision of the System Agreement that prohibits sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. The LPSC’s complaint challenges sales made beginning in 2002 and requests refunds. On July 20, 2009, the Utility operating companies filed a response to the complaint requesting that the FERC dismiss the complaint on the merits without hearing because the LPSC has failed to meet its burden of showing any violation of the System Agreement and failed to produce any evidence of imprudent action by the Entergy System. In their response, the Utility operating companies explained that the System Agreement clearly contemplates that the Utility operating companies may make sales to third parties for their own account, subject to the requirement that those sales be included in the load (or load shape) for the applicable Utility operating company. The response further explains that the FERC already has determined that Entergy Arkansas’s short-term wholesale sales did not trigger the “right-of-first-refusal” provision of the System Agreement. While the D.C. Circuit recently determined that the “right-of-first-refusal” issue was not properly before the FERC at the time of its earlier decision on the issue, the LPSC has raised no additional claims or facts that would warrant the FERC reaching a different conclusion. On December 7, 2009, the FERC issued an order setting the matter for hearing and settlement procedures.

The LPSC filed direct testimony in the proceeding alleging, among other things, (1) that Entergy violated the System Agreement by permitting Entergy Arkansas to make non-requirements sales to non-affiliated third parties rather than making such energy available to the other Utility operating companies’ customers; and (2) that over the period 2000 - 2009, these non-requirements sales caused harm to the Utility operating companies’ customers of $144 million and these customers should be compensated for this harm by Entergy. In subsequent testimony, the LPSC modified its original damages claim in favor of quantifying damages by re-running intra-system bills, which has not occurred. The Utility operating companies believe the LPSC's allegations are without merit. A hearing in the matter was held in August 2010.

In December 2010 the ALJ issued an initial decision. The ALJ found that the System Agreement allowed for Entergy Arkansas to make the sales to third parties but concluded that the sales should be accounted for in the same manner as joint account sales. The ALJ concluded that “shareholders” should make refunds of the damages to the Utility operating companies, along with interest. Entergy Corporation, or an Entergy Corporation subsidiary, is the shareholder of each of the Utility operating companies. Entergy disagrees with several aspects of the ALJ’s initial decision and in January 2011 filed with the FERC exceptions to the decision. FERC consideration of the initial decision is pending. Entergy is unable to estimate the potential damages in this matter because certain aspects of how the refunds would be calculated require clarification by the FERC.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Storm Cost Recovery Filings with Retail Regulators

Entergy Arkansas

In January 2009 a severe ice storm caused significant damage to Entergy Arkansas's transmission and distribution lines, equipment, poles, and other facilities. A law was enacted in April 2009 in Arkansas that authorizes securitization of storm damage restoration costs. In June 2010 the APSC issued a financing order authorizing the issuance of approximately $126.3 million in storm cost recovery bonds, which includes carrying costs of $11.5 million and $4.6 million of up-front financing costs. See Note 5 to the financial statements for a discussion of the August 2010 issuance of the securitization bonds.

Entergy Gulf States Louisiana and Entergy Louisiana

Hurricane Gustav and Hurricane Ike

In September 2008, Hurricane Gustav and Hurricane Ike caused catastrophic damage to Entergy's service territory. Entergy Gulf States Louisiana and Entergy Louisiana filed their Hurricane Gustav and Hurricane Ike storm cost recovery case with the LPSC in May 2009. In September 2009, Entergy Gulf States Louisiana and Entergy Louisiana and the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, filed with the LPSC an application requesting that the LPSC grant financing orders authorizing the financing of Entergy Gulf States Louisiana’s and Entergy Louisiana’s storm costs, storm reserves, and issuance costs pursuant to Act 55 of the Louisiana Regular Session of 2007 (Act 55 financings). Entergy Gulf States Louisiana’s and Entergy Louisiana’s Hurricane Katrina and Hurricane Rita storm costs were financed primarily by Act 55 financings, as discussed below. Entergy Gulf States Louisiana and Entergy Louisiana also filed an application requesting LPSC approval for ancillary issues including the mechanism to flow charges and Act 55 financing savings to customers via a Storm Cost Offset rider.

In December 2009, Entergy Gulf States Louisiana and Entergy Louisiana entered into a stipulation agreement with the LPSC Staff that provides for total recoverable costs of approximately $234 million for Entergy Gulf States Louisiana and $394 million for Entergy Louisiana, including carrying costs. Under this stipulation, Entergy Gulf States Louisiana agrees not to recover $4.4 million and Entergy Louisiana agrees not to recover $7.2 million of their storm restoration spending. The stipulation also permits replenishing Entergy Gulf States Louisiana's storm reserve in the amount of $90 million and Entergy Louisiana's storm reserve in the amount of $200 million when the Act 55 financings are accomplished. In March and April 2010, Entergy Gulf States Louisiana, Entergy Louisiana, and other parties to the proceeding filed with the LPSC an uncontested stipulated settlement that includes these terms and also includes Entergy Gulf States Louisiana’s and Entergy Louisiana's proposals under the Act 55 financings, which includes a commitment to pass on to customers a minimum of $15.5 million and $27.75 million of customer benefits, respectively, through prospective annual rate reductions of $3.1 million and $5.55 million for five years. A stipulation hearing was held before the ALJ on April 13, 2010. On April 21, 2010, the LPSC approved the settlement and subsequently issued two financing orders and one ratemaking order intended to facilitate the implementation of the Act 55 financings. In June 2010 the Louisiana State Bond Commission approved the Act 55 financings.

In July 2010 the Louisiana Local Government Environmental Facilities and Community Development Authority (LCDA) issued $468.9 million in bonds under Act 55. From the $462.4 million of bond proceeds loaned by the LCDA to the LURC, the LURC deposited $200 million in a restricted escrow account as a storm damage reserve for Entergy Louisiana and transferred $262.4 million directly to Entergy Louisiana. From the bond proceeds received by Entergy Louisiana from the LURC, Entergy Louisiana used $262.4 million to acquire 2,624,297.11 Class B preferred, non-voting, membership interest units of Entergy Holdings Company LLC, a company wholly-owned and consolidated by Entergy, that carry a 9% annual distribution rate. Distributions are payable quarterly commencing on September 15, 2010, and the membership interests have a liquidation price of $100 per unit. The preferred membership interests are callable at the option of Entergy Holdings Company LLC after ten years under the terms of the LLC agreement. The terms of the membership interests include certain financial covenants to which Entergy Holdings Company LLC is subject, including the requirement to maintain a net worth of at least $1 billion.

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Notes to Financial Statements

In July 2010 the LCDA issued another $244.1 million in bonds under Act 55. From the $240.3 million of bond proceeds loaned by the LCDA to the LURC, the LURC deposited $90 million in a restricted escrow account as a storm damage reserve for Entergy Gulf States Louisiana and transferred $150.3 million directly to Entergy Gulf States Louisiana. From the bond proceeds received by Entergy Gulf States Louisiana from the LURC, Entergy Gulf States Louisiana used $150.3 million to acquire 1,502,643.04 Class B preferred, non-voting, membership interest units of Entergy Holdings Company LLC, a company wholly-owned and consolidated by Entergy, that carry a 9% annual distribution rate. Distributions are payable quarterly commencing on September 15, 2010, and the membership interests have a liquidation price of $100 per unit. The preferred membership interests are callable at the option of Entergy Holdings Company LLC after ten years under the terms of the LLC agreement. The terms of the membership interests include certain financial covenants to which Entergy Holdings Company LLC is subject, including the requirement to maintain a net worth of at least $1 billion.

Entergy, Entergy Gulf States Louisiana, and Entergy Louisiana do not report the bonds on their balance sheets because the bonds are the obligation of the LCDA, and there is no recourse against Entergy, Entergy Gulf States Louisiana or Entergy Louisiana in the event of a bond default. To service the bonds, Entergy Gulf States Louisiana and Entergy Louisiana collect a system restoration charge on behalf of the LURC, and remit the collections to the bond indenture trustee. Entergy Gulf States Louisiana and Entergy Louisiana do not report the collections as revenue because they are merely acting as the billing and collection agents for the state.

Hurricane Katrina and Hurricane Rita

In August and September 2005, Hurricanes Katrina and Rita caused catastrophic damage to large portions of the Utility’s service territories in Louisiana, Mississippi, and Texas, including the effect of extensive flooding that resulted from levee breaks in and around the greater New Orleans area. The storms and flooding resulted in widespread power outages, significant damage to electric distribution, transmission, and generation and gas infrastructure, and the loss of sales and customers due to mandatory evacuations and the destruction of homes and businesses.

In March 2008, Entergy Gulf States Louisiana, Entergy Louisiana, and the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, filed at the LPSC an application requesting that the LPSC grant financing orders authorizing the financing of Entergy Gulf States Louisiana and Entergy Louisiana storm costs, storm reserves, and issuance costs pursuant to Act 55 of the Louisiana Legislature (Act 55 financings). The Act 55 financings are expected to produce additional customer benefits as compared to traditional securitization. Entergy Gulf States Louisiana and Entergy Louisiana also filed an application requesting LPSC approval for ancillary issues including the mechanism to flow charges and savings to customers via a Storm Cost Offset rider. On April 8, 2008, the Louisiana Public Facilities Authority (LPFA), which is the issuer of the bonds pursuant to the Act 55 financings, approved requests for the Act 55 financings. On April 10, 2008, Entergy Gulf States Louisiana and Entergy Louisiana and the LPSC Staff filed with the LPSC an uncontested stipulated settlement that includes Entergy Gulf States Louisiana and Entergy Louisiana’s proposals under the Act 55 financings, which includes a commitment to pass on to customers a minimum of $10 million and $30 million of customer benefits, respectively, through prospective annual rate reductions of $2 million and $6 million for five years. On April 16, 2008, the LPSC approved the settlement and issued two financing orders and one ratemaking order intended to facilitate implementation of the Act 55 financings. In May 2008, the Louisiana State Bond Commission granted final approval of the Act 55 financings.

In July 2008 the LPFA issued $687.7 million in bonds under the aforementioned Act 55. From the $679 million of bond proceeds loaned by the LPFA to the LURC, the LURC deposited $152 million in a restricted escrow account as a storm damage reserve for Entergy Louisiana and transferred $527 million directly to Entergy Louisiana. From the bond proceeds received by Entergy Louisiana from the LURC, Entergy Louisiana invested $545 million,

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Notes to Financial Statements

including $17.8 million that was withdrawn from the restricted escrow account as approved by the April 16, 2008 LPSC orders, in exchange for 5,449,861.85 Class A preferred, non-voting, membership interest units of Entergy Holdings Company LLC, a company wholly-owned and consolidated by Entergy, that carry a 10% annual distribution rate. Distributions are payable quarterly commencing on September 15, 2008 and have a liquidation price of $100 per unit. The preferred membership interests are callable at the option of Entergy Holdings Company LLC after ten years under the terms of the LLC agreement. The terms of the membership interests include certain financial covenants to which Entergy Holdings Company LLC is subject, including the requirement to maintain a net worth of at least $1 billion.

In August 2008 the LPFA issued $278.4 million in bonds under the aforementioned Act 55. From the $274.7 million of bond proceeds loaned by the LPFA to the LURC, the LURC deposited $87 million in a restricted escrow account as a storm damage reserve for Entergy Gulf States Louisiana and transferred $187.7 million directly to Entergy Gulf States Louisiana. From the bond proceeds received by Entergy Gulf States Louisiana from the LURC, Entergy Gulf States Louisiana invested $189.4 million, including $1.7 million that was withdrawn from the restricted escrow account as approved by the April 16, 2008 LPSC orders, in exchange for 1,893,918.39 Class A preferred, non-voting, membership interest units of Entergy Holdings Company LLC that carry a 10% annual distribution rate. Distributions are payable quarterly commencing on September 15, 2008 and have a liquidation price of $100 per unit. The preferred membership interests are callable at the option of Entergy Holdings Company LLC after ten years under the terms of the LLC agreement. The terms of the membership interests include certain financial covenants to which Entergy Holdings Company LLC is subject, including the requirement to maintain a net worth of at least $1 billion.

Entergy, Entergy Gulf States Louisiana, and Entergy Louisiana do not report the bonds on their balance sheets because the bonds are the obligation of the LPFA, and there is no recourse against Entergy, Entergy Gulf States Louisiana or Entergy Louisiana in the event of a bond default. To service the bonds, Entergy Gulf States Louisiana and Entergy Louisiana collect a system restoration charge on behalf of the LURC, and remit the collections to the bond indenture trustee. Entergy, Entergy Gulf States Louisiana, and Entergy Louisiana do not report the collections as revenue because they are merely acting as the billing and collection agent for the state.

Entergy New Orleans

In December 2005 the U.S. Congress passed the Katrina Relief Bill, a hurricane aid package that included Community Development Block Grant (CDBG) funding (for the states affected by Hurricanes Katrina, Rita, and Wilma) that allowed state and local leaders to fund individual recovery priorities. In March 2007 the City Council certified that Entergy New Orleans incurred $205 million in storm-related costs through December 2006 that are eligible for CDBG funding under the state action plan. Entergy New Orleans received $180.8 million of CDBG funds in 2007 and $19.2 million in 2010.

In October 2006, the City Council approved a rate filing settlement agreement that, among other things, authorized a $75 million storm reserve for damage from future storms, which will be created over a ten-year period through a storm reserve rider that began in March 2007. These storm reserve funds will be held in a restricted escrow account.

Entergy Texas

Entergy Texas filed an application in April 2009 seeking a determination that $577.5 million of Hurricane Ike and Hurricane Gustav restoration costs are recoverable, including estimated costs for work to be completed. On August 5, 2009, Entergy Texas submitted to the ALJ an unopposed settlement agreement intended to resolve all issues in the storm cost recovery case. Under the terms of the agreement $566.4 million, plus carrying costs, are eligible for recovery. Insurance proceeds will be credited as an offset to the securitized amount. Of the $11.1 million difference between Entergy Texas’s request and the amount agreed to, which is part of the black box agreement and not

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

directly attributable to any specific individual issues raised, $6.8 million is operation and maintenance expense for which Entergy Texas recorded a charge in the second quarter 2009. The remaining $4.3 million was recorded as utility plant. The PUCT approved the settlement in August 2009, and in September 2009 the PUCT approved recovery of the costs, plus carrying costs, by securitization. See Note 5 to the financial statements for a discussion of the November 2009 issuance of the securitization bonds.

New Nuclear Generation Development Costs

Pursuant to the Mississippi Baseload Act and the Mississippi Public Utilities Act, Entergy Mississippi is developing a project option for new nuclear generation at Grand Gulf Nuclear Station. This project is in the early stages, and several issues remain to be addressed over time before significant additional capital would be committed to this project. In 2010, Entergy Mississippi paid for and has recognized on its books $49 million in costs associated with the development of new nuclear generation at Grand Gulf; these costs previously had been recorded on the books of Entergy New Nuclear Utility Development, LLC, a System Energy subsidiary. In October 2010, Entergy Mississippi filed an application with the MPSC requesting that the MPSC determine that it is in the public interest to preserve the option to construct new nuclear generation at Grand Gulf and that the MPSC approve the deferral of Entergy Mississippi’s costs incurred to date and in the future related to this project, including the accrual of AFUDC or similar carrying charges. In October 2011, Entergy Mississippi and the Mississippi Public Utilities Staff filed with the MPSC a joint stipulation. The stipulation states that there should be a deferral of the $57 million of costs incurred through September 2011 in connection with planning, evaluation, monitoring, and other and related generation resource development activities for new nuclear generation at Grand Gulf. The costs shall be treated as a regulatory asset until the proceeding is resolved. The Mississippi Public Utilities Staff and Entergy Mississippi also agree that the MPSC should conduct a hearing during 2012 to consider the relief requested by Entergy Mississippi in its application, including evidence regarding whether costs incurred in connection with planning, evaluation, monitoring, and other and related generation resource development activities for new nuclear generation at Grand Gulf were prudently incurred and are otherwise allowable. The Mississippi Public Utilities Staff and Entergy Mississippi further agree that such prudently incurred costs shall be recoverable in a manner to be determined by the MPSC. In the Stipulation, the Mississippi Public Utilities Staff and Entergy Mississippi agree that the development of a nuclear unit project option is consistent with the Mississippi Baseload Act. The Mississippi Public Utilities Staff and Entergy Mississippi further agree that the deferral of costs incurred in connection with planning, evaluation, monitoring, and other and related generation resource development activities for new nuclear generation at Grand Gulf also is consistent with the Mississippi Baseload Act. Entergy Mississippi will not accrue carrying charges or continue to accrue AFUDC on the costs, pending the outcome of the proceeding. The MPSC approved the stipulation in November 2011.

Error in the Allocation of Transmission Costs

In the fourth quarter 2011, Entergy determined that the allocation of transmission costs among the Utility operating companies under the System Agreement inadvertently excluded certain transmission costs. This exclusion resulted in the over or understatement of System Agreement bills among the Utility operating companies during the period from 1996 through the third quarter 2011. The effect was immaterial to the balance sheets, results of operations, and cash flows of Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and Entergy Texas for all prior reporting periods and on a cumulative basis. Therefore, cumulative adjustments were recorded in the fourth quarter 2011 to correct for the amounts previously misstated. These adjustments increased (reduced) 2011 income before income taxes by $8.9 million for Entergy Arkansas, $5.8 million for Entergy Gulf States Louisiana, ($17.1) million for Entergy Louisiana, and ($3.1) million for Entergy Texas.

The effect was also immaterial to the balance sheets, results of operations, and cash flows of Entergy Mississippi and Entergy New Orleans for all prior reporting periods. Correcting the cumulative effect of the error in the fourth quarter 2011 would have been material, however, to the results of operations of Entergy Mississippi and Entergy New Orleans. Accordingly, Entergy Mississippi and Entergy New Orleans are restating their 2009 and 2010 financial statements. The effects of the correction for 2009 and 2010 were the following increases or (decreases) to the previously reported amounts for the following financial statement items:

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Notes to Financial Statements

	Income before income taxes	Income taxes	Net income	Accounts receivable- associated companies	Taxes accrued/ Prepayments and other
	(In Millions)

Entergy Mississippi
2009	$2.8	$1.1	$1.7	$-	$-
2010	$2.7	$1.0	$1.7	$11.1	$4.3

Entergy New Orleans
2009	($0.9)	($0.4)	($0.5)	$-	$-
2010	$0.2	$0.1	$0.1	($5.8)	$2.3

The cumulative effects of the correction on beginning retained earnings for 2009 were the following increase and (decrease):

	Cumulative Effect of the Correction on Beginning Retained Earnings for 2009

Entergy Mississippi	$3.5 million
Entergy New Orleans	($3.0 million)

There was no effect on the Entergy financial statements for any period because the error only involved the allocation of shared transmission costs among the Utility operating companies under the System Agreement and, therefore, had no effect on a consolidated basis.

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Notes to Financial Statements

NOTE 3. INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Income tax expenses from continuing operations for 2011, 2010, and 2009 for Entergy Corporation and Subsidiaries consist of the following:

	2011	2010	2009
	(In Thousands)
Current:
Federal	$452,713	$145,161	($433,105)
Foreign	130	131	154
State	152,711	19,313	(108,552)
Total	605,554	164,605	(541,503)
Deferred and non-current -- net	(311,708)	468,698	1,191,418
Investment tax credit
adjustments -- net	(7,583)	(16,064)	(17,175)
Income tax expense from
continuing operations	$286,263	$617,239	$632,740

Income tax expenses (benefit) for 2011, 2010, and 2009 for Entergy’s Registrant Subsidiaries consist of the following:

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy	System
2011	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas	Energy
	(In Thousands)
Current:
Federal	($12,448)	($30,106)	($136,800)	($9,466)	$14,641	($33,045)	$139,529
State	(1,751)	15,950	34,832	6,069	1,724	3,153	16,825
Total	(14,199)	(14,156)	(101,968)	(3,397)	16,365	(29,892)	156,354
Deferred and non-current -- net	148,978	105,827	(265,046)	32,380	(201)	80,993	(84,505)
Investment tax credit
adjustments -- net	(2,014)	(3,358)	(3,197)	(182)	(302)	(1,609)	3,104
Income taxes (benefit)	$132,765	$88,313	($370,211)	$28,801	$15,862	$49,492	$74,953

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy	System
2010	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas	Energy
	(In Thousands)
Current:
Federal	$114,821	$196,230	$73,174	$13,722	($114,382)	($10,607)	($4,102)
State	(9,200)	481	(4,324)	5,959	1,427	1,060	3,328
Total	105,621	196,711	68,850	19,681	(112,955)	(9,547)	(774)
Deferred and non-current -- net	10,328	(117,426)	918	31,415	129,880	53,539	60,305
Investment tax credit
adjustments -- net	(3,005)	(3,407)	(3,222)	(985)	(324)	(1,609)	(3,482)
Income taxes (benefit)	$112,944	$75,878	$66,546	$50,111	$16,601	$42,383	$56,049

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Notes to Financial Statements

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy		Entergy	System
2009	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans		Texas	Energy
	(In Thousands)
Current:
Federal	($37,544)	($203,651)	$12,387	$20,279	$160,552	($72,207)		$73,183
State	22,710	(12,416)	(49,843)	(2,181)	1,098	2,478		(12,667)
Total	(14,834)	(216,067)	(37,456)	18,098	161,650	(69,729)		60,516
Deferred and non-current -- net	100,584	308,659	85,728	26,400	(145,981)	108,253		39,866
Investment tax credit
adjustments -- net	(3,994)	(3,407)	(3,222)	(1,103)	(323)	(1,609)		(3,481)
Income taxes	$81,756	$89,185	$45,050	$43,395	$15,346	$36,915		$96,901

Total income taxes for Entergy Corporation and Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2011, 2010, and 2009 are:

	2011	2010	2009
	(In Thousands)

Net income attributable to Entergy Corporation	$1,346,439	$1,250,242	$1,231,092
Preferred dividend requirements of subsidiaries	20,933	20,063	19,958
Consolidated net income	1,367,372	1,270,305	1,251,050
Income taxes	286,263	617,239	632,740
Income before income taxes	$1,653,635	$1,887,544	$1,883,790

Computed at statutory rate (35%)	$578,772	$660,640	$659,327
Increases (reductions) in tax resulting from:
State income taxes net of federal income tax effect	93,940	40,530	65,241
Regulatory differences - utility plant items	39,970	31,473	57,383
Equity component of AFUDC	(30,184)	(16,542)	(17,741)
Amortization of investment tax credits	(14,962)	(15,980)	(16,745)
Net-of-tax regulatory liability (a)	65,357	-	-
Deferred tax reversal on PPA settlement (a)	(421,819)	-	-
Write-off of reorganization costs	-	(19,974)	-
Tax law change-Medicare Part D	-	13,616	-
Decommissioning trust fund basis	-	-	(7,917)
Capital gains / (losses)	-	-	(28,051)
Flow-through / permanent differences	(17,848)	(26,370)	(31,745)
Provision for uncertain tax positions	2,698	(43,115)	(17,435)
Valuation allowance	-	-	(40,795)
Other - net	(9,661)	(7,039)	11,218
Total income taxes as reported	$286,263	$617,239	$632,740

Effective Income Tax Rate	17.3%	32.7%	33.6%

(a) See "Income Tax Audits - 2006-2007 IRS Audit" below for discussion of these items.

Table of Contents

Entergy Corporation and Subsidiaries

Notes to Financial Statements

Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory income tax rate to income before taxes. The reasons for the differences for the years 2011, 2010, and 2009 are:

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy	System
2011	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas	Energy
	(In Thousands)

Net income	$164,891	$203,027	$473,923	$108,729	$35,976	$80,845	$64,197
Income taxes (benefit)	132,765	88,313	(370,211)	28,801	15,862	49,492	74,953
Pretax income	$297,656	$291,340	$103,712	$137,530	$51,838	$130,337	$139,150

Computed at statutory rate (35%)	$104,180	$101,969	$36,299	$48,136	$18,143	$45,618	$48,703
Increases (reductions) in tax
resulting from:
State income taxes net of
federal income tax effect	13,727	9,618	943	3,211	3,350	2,033	4,436
Regulatory differences -
utility plant items	10,079	8,379	1,404	2,038	3,860	4,003	10,207
Equity component of AFUDC	(3,363)	(3,181)	(11,315)	(2,963)	(215)	(1,322)	(7,825)
Amortization of investment
tax credits	(1,992)	(3,336)	(3,168)	(960)	(295)	(1,596)	(3,480)
Net-of-tax regulatory liability (a)	-	-	65,357	-	-	-	-
Deferred tax reversal on PPA
settlement (a)	-	-	(421,819)	-	-	-	-
Flow-through / permanent
differences	(1,365)	(836)	(1,285)	304	(4,983)	88	529
Non-taxable
dividend income	-	(11,364)	(27,336)	-	-	-	-
Benefit of Entergy Corporation
expenses	-	(5,694)	-	(21,248)	(6,235)	(16)	16,559
Provision for uncertain
tax positions	12,016	(7,144)	(4,880)	(2)	2,241	717	5,878
Other -- net	(517)	(98)	(4,411)	285	(4)	(33)	(54)
Total income taxes (benefit)	$132,765	$88,313	($370,211)	$28,801	$15,862	$49,492	$74,953

Effective Income Tax Rate	44.6%	30.3%	-357.0%	20.9%	30.6%	38.0%	53.9%

(a) See "Income Tax Audits - 2006-2007 IRS Audit" below for discussion of these items.

Table of Contents

Entergy Corporation and Subsidiaries

Notes to Financial Statements

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy	System
2010	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas	Energy
	(In Thousands)

Net income	$172,618	$190,738	$231,435	$85,377	$31,114	$66,200	$82,624
Income taxes	112,944	75,878	66,546	50,111	16,601	42,383	56,049
Pretax income	$285,562	$266,616	$297,981	$135,488	$47,715	$108,583	$138,673

Computed at statutory rate (35%)	$99,947	$93,316	$104,293	$47,421	$16,700	$38,004	$48,536
Increases (reductions) in tax
resulting from:
State income taxes net of
federal income tax effect	13,156	1,142	(10,618)	1,245	1,387	424	2,206
Regulatory differences -
utility plant items	6,126	(4,004)	7,374	3,455	3,999	4,089	10,435
Equity component of AFUDC	(144)	(1,547)	(8,361)	(1,643)	(184)	(1,525)	(3,138)
Amortization of investment
tax credits	(2,983)	(3,309)	(3,192)	(972)	(313)	(1,596)	(3,480)
Flow-through / permanent
differences	(1,235)	(7,996)	(754)	153	(4,883)	236	(497)
Non-taxable
dividend income	-	(9,189)	(23,603)	-	-	-	-
Provision for uncertain
tax positions	(2,100)	7,200	2,200	700	(300)	2,800	2,090
Other -- net	177	265	(793)	(248)	195	(49)	(103)
Total income taxes	$112,944	$75,878	$66,546	$50,111	$16,601	$42,383	$56,049

Effective Income Tax Rate	39.6%	28.5%	22.3%	37.0%	34.8%	39.0%	40.4%

Table of Contents

Entergy Corporation and Subsidiaries

Notes to Financial Statements

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy	System
2009	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas	Energy
	(In Thousands)

Net income	$66,875	$153,047	$232,845	$79,367	$30,479	$63,841	$48,908
Income taxes	81,756	89,185	45,050	43,395	15,346	36,915	96,901
Pretax income	$148,631	$242,232	$277,895	$122,762	$45,825	$100,756	$145,809

Computed at statutory rate (35%)	$52,021	$84,781	$97,263	$42,967	$16,039	$35,264	$51,033
Increases (reductions) in tax
resulting from:
State income taxes net of
federal income tax effect	9,617	6,487	5,095	2,508	1,339	1,509	4,033
Regulatory differences -
utility plant items	19,275	10,303	14,463	1,365	(55)	2,008	10,024
Equity component of AFUDC	(1,827)	(1,898)	(9,796)	(1,037)	(82)	(1,831)	(1,270)
Amortization of investment
tax credits	(3,972)	(3,088)	(3,192)	(1,092)	(324)	(1,596)	(3,480)
Flow-through / permanent
differences	4,158	1,208	2,257	718	(2,218)	293	(3,192)
Non-taxable
dividend income	-	(6,627)	(19,075)	-	-	-	-
Benefit of Entergy Corporation
expenses	978	(170)	(24,231)	(2,841)	31	-	35,027
Provision for uncertain
tax positions	-	(5,400)	(17,700)	800	(400)	600	4,900
Other -- net	1,506	3,589	(34)	7	1,016	668	(174)
Total income taxes	$81,756	$89,185	$45,050	$43,395	$15,346	$36,915	$96,901

Effective Income Tax Rate	55.0%	36.8%	16.2%	35.3%	33.5%	36.6%	66.5%

Table of Contents

Entergy Corporation and Subsidiaries

Notes to Financial Statements

Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and Subsidiaries as of December 31, 2011 and 2010 are as follows:

	2011	2010
	(In Thousands)
Deferred tax liabilities:
Plant basis differences - net	($7,349,990)	($6,572,627)
Regulatory asset for income taxes - net	(430,807)	(449,266)
Power purchase agreements	(17,138)	(265,429)
Nuclear decommissioning trusts	(553,558)	(439,481)
Other	(686,006)	(679,302)
Total	(9,037,499)	(8,406,105)

Deferred tax assets:
Accumulated deferred investment
tax credit	108,338	111,170
Pension and other post-employment benefits	315,134	161,730
Nuclear decommissioning liabilities	612,945	285,889
Sale and leaseback	217,430	256,157
Provision for regulatory adjustments	97,607	100,504
Provision for contingencies	28,504	28,554
Unbilled/deferred revenues	12,217	18,642
Customer deposits	14,825	15,724
Net operating loss carryforwards	253,518	123,710
Capital losses	12,995	56,602
Other	96,676	19,009
Valuation allowance	(85,615)	(70,089)
Total	1,684,574	1,107,602

Noncurrent accrued taxes (including unrecognized
tax benefits)	(814,597)	(1,261,455)

Accumulated deferred income taxes and taxes accrued	($8,167,522)	($8,559,958)

Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2011 are as follows:

Carryover Description	Carryover Amount	Year(s) of expiration

Federal net operating losses	$9 billion	2023-2031
State net operating losses	$8 billion	2012-2031
State capital losses	$162 million	2013-2015
Federal minimum tax credits	$79 million	never
Other federal and state credits	$80 million	2012-2031

Table of Contents

Entergy Corporation and Subsidiaries

Notes to Financial Statements

As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers, tax credit carryovers, and other tax attributes reflected on income tax returns.

Because it is more likely than not that the benefit from certain state net operating and capital loss carryovers will not be utilized, a valuation allowance of $66 million and $13 million has been provided on the deferred tax assets relating to these state net operating and capital loss carryovers, respectively.

Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries as of December 31, 2011 and 2010 are as follows:

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy	System
2011	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas	Energy
	(In Thousands)

Deferred tax liabilities:
Plant basis differences - net	($1,375,502)	($1,224,422)	($1,085,047)	($608,596)	($169,538)	($892,707)	($505,369)
Regulatory asset for income taxes - net	(64,204)	(140,644)	(121,388)	(28,183)	70,973	(59,812)	(87,550)
Power purchase agreements	94	3,938	(1)	2,383	22	2,547	-
Nuclear decommissioning trusts	(53,789)	(21,096)	(22,441)	-	-	-	(19,138)
Deferred fuel	(82,452)	(1,225)	(4,285)	718	(331)	3,932	(8)
Other	(107,558)	(1,532)	(26,373)	(10,193)	(18,319)	(14,097)	(9,333)
Total	($1,683,411)	($1,384,981)	($1,259,535)	($643,871)	($117,193)	($960,137)	($621,398)

Deferred tax assets:
Accumulated deferred investment
tax credits	16,843	31,367	28,197	2,437	592	6,769	22,133
Pension and OPEB	(75,399)	92,602	19,866	(30,390)	(11,713)	(41,964)	(19,593)
Nuclear decommissioning liabilities	(104,862)	(38,683)	56,399	-	-	-	(47,360)
Sale and leaseback	-	-	66,801	-	-	-	150,629
Provision for regulatory adjustments	-	97,608	-	-	-	-	-
Provision for contingencies	4,167	90	3,940	2,465	10,121	2,299	-
Unbilled/deferred revenues	15,222	(21,918)	(7,108)	8,990	2,707	14,324	-
Customer deposits	7,019	618	5,699	1,379	109	-	-
Rate refund	11,627	-	134	-	2	(3,924)	-
Net operating loss carryforwards	-	-	39,153	-	-	58,546	-
Other	3,485	27,392	18,824	4,826	5,248	37,734	25,724
Total	(121,898)	189,076	231,905	(10,293)	7,066	73,784	131,533

Noncurrent accrued taxes (including
unrecognized tax benefits)	(27,718)	(206,752)	(75,750)	(6,271)	(27,859)	39,799	(165,981)

Accumulated deferred income
taxes and taxes accrued	($1,833,027)	($1,402,657)	($1,103,380)	($660,435)	($137,986)	($846,554)	($655,846)

Table of Contents

Entergy Corporation and Subsidiaries

Notes to Financial Statements

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy	System
2010	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas	Energy
	(In Thousands)

Deferred tax liabilities:
Plant basis differences - net	($1,213,900)	($1,114,183)	($1,135,092)	($564,928)	($206,739)	($881,037)	($474,446)
Regulatory asset for income taxes - net	(87,848)	(132,145)	(138,131)	(24,649)	66,251	(53,906)	(78,836)
Power purchase agreements	582	102,581	(417,388)	(766)	(61)	(6,851)	-
Nuclear decommissioning trusts	(9,968)	(978)	(3,806)	-	-	-	(4,102)
Deferred fuel	(24,210)	(935)	(7,584)	(4,521)	(626)	10,025	(60)
Other	(123,524)	(2,505)	(21,971)	(10,991)	(13,839)	(19,712)	(15,234)
Total	($1,458,868)	($1,148,165)	($1,723,972)	($605,855)	($155,014)	($951,481)	($572,678)

Deferred tax assets:
Accumulated deferred investment
tax credits	17,623	32,651	29,417	2,502	706	7,327	20,944
Pension and OPEB	(64,774)	70,954	7,922	(27,111)	(11,527)	(38,152)	(18,255)
Nuclear decommissioning liabilities	(173,666)	(41,829)	-	-	-	-	(69,610)
Sale and leaseback	-	-	80,117	-	-	-	176,040
Provision for regulatory adjustments	-	100,504	-	-	-	-	-
Unbilled/deferred revenues	8,056	(23,853)	6,892	8,914	1,538	15,775	-
Customer deposits	7,907	618	5,699	1,391	109	-	-
Rate refund	10,873	(5,386)	131	-	-	(4,008)	-
Net operating loss carryforwards	-	40	41	-	8	139,859	-
Other	13,589	26,468	25,897	14,585	21,310	28,508	16,486
Total	(180,392)	160,167	156,116	281	12,144	149,309	125,605

Noncurrent accrued taxes (including
unrecognized tax benefits)	(104,925)	(419,125)	(321,757)	(55,585)	(22,328)	17,256	(178,447)

Accumulated deferred income
taxes and taxes accrued	($1,744,185)	($1,407,123)	($1,889,613)	($661,159)	($165,198)	($784,916)	($625,520)

The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2011 are as follows:

Entergy

Arkansas

Entergy

Gulf States

Louisiana

Entergy

Louisiana

Entergy

Mississippi

Entergy

New Orleans

Entergy

Texas

System

Energy

Federal net operating

losses

$374 million

$621 million

$197 million

$3 million

Year(s) of expiration

2028-2031

N/A

2029-2031

N/A

2028-2029

2031

State net operating losses

$28 million

$207 million

$975 million

Year(s) of expiration

2025

2023-2024

2023-2025

N/A

Federal minimum tax

credits

$10 million

$18 million

$2 million

$1 million

Year(s) of expiration

never

N/A

never

Other federal credits

$2 million

$1 million

Year(s) of expiration

2024-2030

N/A

2024-2030

State credits

$8.3 million

$3.8 million

$12.8 million

Year(s) of expiration

N/A

2013-2016

N/A

2012-2027

2015-2016

Table of Contents

Entergy Corporation and Subsidiaries

Notes to Financial Statements

Unrecognized tax benefits

Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return, but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits is as follows:

	2011	2010	2009
	(In Thousands)

Gross balance at January 1	$4,949,788	$4,050,491	$1,825,447
Additions based on tax positions related to the current year	211,966	480,843	2,286,759
Additions for tax positions of prior years	332,744	871,682	697,615
Reductions for tax positions of prior years	(259,895)	(438,460)	(372,862)
Settlements	(841,528)	(10,462)	(385,321)
Lapse of statute of limitations	(5,295)	(4,306)	(1,147)
Gross balance at December 31	4,387,780	4,949,788	4,050,491
Offsets to gross unrecognized tax benefits:
Credit and loss carryovers	(3,212,397)	(3,771,301)	(3,349,589)
Cash paid to taxing authorities	(363,266)	(373,000)	(373,000)
Unrecognized tax benefits net of unused tax attributes and payments (1)	$812,117	$805,487	$327,902

(1)	Potential tax liability above what is payable on tax returns

The balances of unrecognized tax benefits include $521 million, $605 million, and $522 million as of December 31, 2011, 2010, and 2009, respectively, which, if recognized, would lower the effective income tax rates. Because of the effect of deferred tax accounting, the remaining balances of unrecognized tax benefits of $3.867 billion, $4.345 billion, and $3.528 billion as of December 31, 2011, 2010, and 2009, respectively, if disallowed, would not affect the annual effective income tax rate but would accelerate the payment of cash to the taxing authority to an earlier period.

Entergy has made deposits with the IRS against its potential liabilities arising from audit adjustments and settlements related to its uncertain tax positions. Deposits are expected to be made to the IRS as the cash tax benefits of uncertain tax positions are realized. As of December 31, 2011, Entergy has deposits of $363 million on account with the IRS to cover its uncertain tax positions.

Entergy accrues interest expense, if any, related to unrecognized tax benefits in income tax expense. Entergy’s December 31, 2011, 2010, and 2009 accrued balance for the possible payment of interest is approximately $99 million, $45 million, and $48 million, respectively.

Table of Contents

Entergy Corporation and Subsidiaries

Notes to Financial Statements

A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2011, 2010, and 2009 is as follows:

2011	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)

Gross balance at January 1, 2011	$240,239	$353,886	$505,188	$24,163	$18,176	$14,229	$224,518
Additions based on tax
positions related to the
current year	11,216	9,398	8,748	457	50,212	1,760	44,419
Additions for tax positions
of prior years	44,202	50,944	21,052	21,902	7,343	7,533	14,200
Reductions for tax
positions of prior years	(3,255)	(21,719)	(27,991)	(5,022)	(12,289)	(3,432)	(4,942)
Settlements	43,091	(2,016)	(60,810)	(30,448)	(7,390)	(865)	2,988
Gross balance at December 31, 2011	335,493	390,493	446,187	11,052	56,052	19,225	281,183
Offsets to gross unrecognized
tax benefits:
Loss carryovers	(146,429)	(26,394)	(216,720)	(5,930)	(1,211)	(10,645)	(10,752)
Cash paid to taxing authorities	(75,977)	(45,493)	0	(7,556)	(1,174)	(1,376)	(41,878)
Unrecognized tax benefits net of
unused tax attributes and payments	$113,087	$318,606	$229,467	($2,434)	$53,667	$7,204	$228,553

2010	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)

Gross balance at January 1, 2010	$293,920	$311,311	$352,577	$17,137	($53,295)	$32,299	$211,247
Additions based on tax
positions related to the
current year	38,205	87,755	183,188	4,679	173	5,169	16,829
Additions for tax positions
of prior years	1,838	25,960	34,236	6,857	72,169	5,868	10,402
Reductions for tax
positions of prior years	(92,699)	(71,033)	(64,868)	(4,469)	(863)	(29,100)	(13,116)
Settlements	(1,025)	(107)	55	(41)	(8)	(7)	(844)
Gross balance at December 31, 2010	240,239	353,886	505,188	24,163	18,176	14,229	224,518
Offsets to gross unrecognized
tax benefits:
Loss carryovers	(123,968)	(29,257)	(131,805)	(6,477)	(3,751)	(6,269)	(10,487)
Cash paid to taxing authorities	(75,977)	(45,493)	-	(7,556)	(1,174)	(1,376)	(41,878)
Unrecognized tax benefits net of
unused tax attributes and payments	$40,294	$279,136	$373,383	$10,130	$13,251	$6,584	$172,153

Table of Contents

Entergy Corporation and Subsidiaries

Notes to Financial Statements

2009	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)

Gross balance at January 1, 2009	$240,203	$275,378	$298,650	$31,724	$26,050	$39,202	$172,168
Additions based on tax
positions related to the
current year	9,826	5,436	10,197	283	17	97	6,812
Additions for tax positions
of prior years	80,968	102,466	108,399	1,256	109	28,821	30,586
Reductions for tax
positions of prior years	(22,830)	(33,000)	(45,613)	(4,235)	(70,391)	(17,853)	(244)
Settlements	(14,247)	(38,969)	(19,056)	(11,891)	(9,080)	(17,968)	1,925
Gross balance at December 31, 2009	293,920	311,311	352,577	17,137	(53,295)	32,299	211,247
Offsets to gross unrecognized
tax benefits:
Loss carryovers	(39,847)	(20,031)	(70,428)	(1,618)	(633)	(30,921)	(1,297)
Cash paid to taxing authorities	(75,977)	(45,493)	-	(7,556)	(1,174)	(1,376)	(41,878)
Unrecognized tax benefits net of
unused tax attributes and payments	$178,096	$245,787	$282,149	$7,963	($55,102)	$2	$168,072

The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would affect the effective income tax rate as follows:

	December 31, 2011	December 31, 2010	December 31, 2009
	(In Millions)

Entergy Arkansas	$-	$0.2	$1.2
Entergy Gulf States Louisiana	$107.9	$129.6	$69.8
Entergy Louisiana	$281.3	$286.7	$192.7
Entergy Mississippi	$3.8	$5.3	$3.3
Entergy New Orleans	$-	$-	$0.3
Entergy Texas	$7.3	$6.0	$1.2
System Energy	$-	$12.1	$8.7

The Registrant Subsidiaries accrue interest and penalties related to unrecognized tax benefits in income tax expense. Accrued balances for the possible payment of interest and penalties are as follows:

	December 31, 2011	December 31, 2010	December 31, 2009
	(In Millions)

Entergy Arkansas	$11.4	$-	$0.7
Entergy Gulf States Louisiana	$14.4	$9.7	$2.3
Entergy Louisiana	$0.8	$3.3	$1.2
Entergy Mississippi	$1.7	$1.6	$2.1
Entergy New Orleans	$2.4	$-	$0.3
Entergy Texas	$0.1	$0.1	$0.2
System Energy	$18.5	$8.2	$7.2

Table of Contents

Entergy Corporation and Subsidiaries

Notes to Financial Statements

Income Tax Litigation

In October 2010 the United States Tax Court entered a decision in favor of Entergy for tax years 1997 and 1998. The issues decided by the Tax Court are as follows:

·	The ability to credit the U.K. Windfall Tax against U.S. tax as a foreign tax credit. The U.K. Windfall Tax relates to Entergy’s former investment in London Electricity.

·	The validity of Entergy’s change in method of tax accounting for street lighting assets and the related increase in depreciation deductions.

The IRS did not appeal street lighting depreciation, and that matter is considered final. The IRS filed an appeal of the U.K. Windfall Tax decision, however, with the United States Court of Appeals for the Fifth Circuit in December 2010. Oral arguments were heard in November 2011, and a decision is pending.

Concurrent with the Tax Court’s issuance of a favorable decision regarding the above issues, the Tax Court issued a favorable decision in a separate proceeding, PPL Corp. v. Commissioner, regarding the creditability of the U.K. Windfall Tax. The IRS appealed the PPL decision to the United States Court of Appeals for the Third Circuit. In December 2011, the Third Circuit reversed the Tax Court’s holding in PPL Corp. v. Commissioner, stating that the U.K. tax was not eligible for the foreign tax credit. Entergy is awaiting a decision in its proceeding before the Fifth Circuit Court of Appeals. Although Entergy believes that the Third Circuit opinion is incorrect, its decision constitutes adverse, although not controlling authority. After considering the Third Circuit decision, in the fourth quarter 2011, Entergy revised its provision for uncertain tax positions associated with this issue.

The total tax included in IRS Notices of Deficiency relating to the U.K. Windfall Tax credit issue is $82 million. The total tax and interest associated with this issue for all years is approximately $239 million. This assumes that Entergy would utilize a portion of its cash deposits discussed in “Unrecognized tax benefits” above to offset underpayment interest.

In February 2008 the IRS issued a Statutory Notice of Deficiency for the year 2000. The deficiency resulted from a disallowance of the same two 1997-1998 issues discussed above as well as one additional issue. That issue is depreciation deductions that resulted from Entergy’s purchase price allocations on its acquisitions of its non-utility nuclear plants. Entergy filed a Tax Court petition in May 2008 challenging the three issues in dispute. In June 2010 a trial on these issues was held in Washington, D.C. In February 2011 a joint stipulation of settled issues was filed addressing the depreciation issue in the Tax Court case. As a result, the IRS agreed that Entergy was entitled to allocate all of the cash consideration to plant and equipment rather than to nuclear decommissioning trusts thereby entitling Entergy to its claimed depreciation.

Income Tax Audits

Entergy and its subsidiaries file U.S. federal and various state and foreign income tax returns. Other than the matters discussed in the Income Tax Litigation section above, the IRS’s and substantially all state taxing authorities’ examinations are completed for years before 2004.

2002-2003 IRS Audit

In September 2009, Entergy entered into a partial agreement with the IRS for the years 2002 and 2003. It is a partial agreement because Entergy did not agree to the IRS’s disallowance of foreign tax credits for the U.K. Windfall Tax and the street lighting depreciation issues as they relate to 2002. As discussed above the, the IRS did not appeal the Tax Court ruling on the street lighting depreciation. Therefore, the U.K. Windfall tax credit issue will be governed by the decision by the Fifth Circuit Court of Appeals for the tax years 1997 and 1998.

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2004-2005 IRS Audit

The IRS issued its 2004-2005 Revenue Agent’s Report (RAR) in May 2009.

In June 2009, Entergy filed a formal protest with the IRS Appeals Division indicating disagreement with certain issues contained in the 2004-2005 RAR. The major issues in dispute are:

·	Depreciation of street lighting assets (Because the IRS did not appeal the Tax Court’s 2010 decision on this issue, it will be fully allowed in the final Appeals Division calculations for this audit).

·	Qualified research expenditures for purposes of the research credit.

·	Inclusion of nuclear decommissioning liabilities in cost of goods sold.

The initial IRS appeals conference to discuss these disputed issues occurred in September 2010. Negotiations are ongoing.

2006-2007 IRS Audit

The IRS issued its 2006-2007 RAR in October 2011. In connection with the 2006-2007 IRS audit and resulting RAR, Entergy resolved the significant issues discussed below.

In August 2011, Entergy entered into a settlement agreement with the IRS relating to the mark-to-market income tax treatment of various wholesale electric power purchase and sale agreements, including Entergy Louisiana’s contract to purchase electricity from the Vidalia hydroelectric facility. See Note 8 to the financial statements for further details regarding this contract and a previous LPSC-approved settlement regarding sharing of tax benefits from the tax treatment of the contract.

With respect to income tax accounting for wholesale electric power purchase agreements, Entergy recognized income for tax purposes of approximately $1.5 billion, which represents a reversal of previously deducted temporary differences on which deferred taxes had been provided. Also in connection with this settlement, Entergy recognized a gain for income tax purposes of approximately $1.03 billion on the formation of a wholly-owned subsidiary in 2005 with a corresponding step-up in the tax basis of depreciable assets resulting in additional tax depreciation at Entergy Louisiana. Because Entergy Louisiana is entitled to deduct additional tax depreciation of $1.03 billion in the future, Entergy Louisiana recorded a deferred tax asset for this additional tax basis. The tax expense associated with the gain is offset by recording the deferred tax asset and by utilization of net operating losses. With the recording of the deferred tax asset, there was a corresponding increase to Entergy Louisiana’s member’s equity account. The agreement with the IRS effectively settled the tax treatment of various wholesale electric power purchase and sale agreements, resulting in the reversal in third quarter 2011 of approximately $422 million of deferred tax liabilities and liabilities for uncertain tax positions at Entergy Louisiana, with a corresponding reduction in income tax expense. Under the terms of an LPSC-approved final settlement, Entergy Louisiana will share over a 15-year period a portion of the benefits of the settlement with its customers, and recorded a $199 million regulatory charge and a corresponding net-of-tax regulatory liability to reflect this obligation.

After consideration of the taxable income recognition and the additional depreciation deductions provided for in the settlement, Entergy’s net operating loss carryover was reduced by approximately $2.5 billion.

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Other Tax Matters

Entergy regularly negotiates with the IRS to achieve settlements. The results of all pending litigations and audit issues could result in significant changes to the amounts of unrecognized tax benefits, as discussed above.

When Entergy Louisiana, Inc. restructured effective December 31, 2005, Entergy Louisiana agreed, under the terms of the merger plan, to indemnify its parent, Entergy Louisiana Holdings, Inc. (formerly, Entergy Louisiana, Inc.) for certain tax obligations that arose from the 2002-2003 IRS partial agreement. Because the agreement with the IRS was settled in the fourth quarter 2009, Entergy Louisiana paid Entergy Louisiana Holdings approximately $289 million pursuant to these intercompany obligations in the fourth quarter 2009.

On November 20, 2009, Entergy Corporation and subsidiaries amended the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement such that Entergy Corporation shall be treated, under all provisions of such Agreement, in a manner that is identical to the treatment afforded all subsidiaries, direct or indirect, of Entergy Corporation.

In the fourth quarter 2009, Entergy filed Applications for Change in Method of Accounting with the IRS for certain costs under Section 263A of the Internal Revenue Code. In the Applications, Entergy proposed to treat the nuclear decommissioning liability associated with the operation of its nuclear power plants as a production cost properly includable in cost of goods sold. The effect of this change for Entergy was a $5.7 billion reduction in 2009 taxable income within the Entergy Wholesale Commodities segment.

In March 2010, Entergy filed an Application for Change in Accounting Method with the IRS. In the application Entergy proposed to change the definition of unit of property for its generation assets to determine the appropriate characterization of costs associated with such units as capital or repair under the Internal Revenue Code and related Treasury Regulations. The effect of this change was an approximate $1.3 billion reduction in 2010 taxable income for Entergy, including reductions of $292 million for Entergy Arkansas, $132 million for Entergy Gulf States Louisiana, $185 million for Entergy Louisiana, $48 million for Entergy Mississippi, $45 million for Entergy Texas, $13 million for Entergy New Orleans, and $180 million for System Energy.

During the second quarter 2011, Entergy filed an Application for Change in Accounting Method with the IRS related to the allocation of overhead costs between production and non-production activities. The accounting method affects the amount of overhead that will be capitalized or deducted for tax purposes. The accounting method is expected to be implemented for the 2014 tax year.

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NOTE 4. REVOLVING CREDIT FACILITIES, LINES OF CREDIT AND SHORT-TERM BORROWINGS (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)

$3,451	$1,920	$28	$1,503

Entergy Corporation’s facility requires it to maintain a consolidated debt ratio of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur.

Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, and Entergy Texas each had credit facilities available as of December 31, 2011 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of December 31, 2011

Entergy Arkansas	April 2012	$78 million (b)	3.25%	-
Entergy Gulf States Louisiana	August 2012	$100 million (c)	0.71%	-
Entergy Louisiana	August 2012	$200 million (d)	0.67%	$50 million
Entergy Mississippi	May 2012	$35 million (e)	2.05%	-
Entergy Mississippi	May 2012	$25 million (e)	2.05%	-
Entergy Mississippi	May 2012	$10 million (e)	2.05%	-
Entergy Texas	August 2012	$100 million (f)	0.77%	-

(a)	The interest rate is the rate as of December 31, 2011 that would be applied to outstanding borrowings under the facility.
(b)	The credit facility requires Entergy Arkansas to maintain a debt ratio of 65% or less of its total capitalization. Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable.
(c)	The credit facility allows Entergy Gulf States Louisiana to issue letters of credit against the borrowing capacity of the facility. As of December 31, 2011, no letters of credit were outstanding. The credit facility requires Entergy Gulf States Louisiana to maintain a consolidated debt ratio of 65% or less of its total capitalization.
(d)	The credit facility allows Entergy Louisiana to issue letters of credit against the borrowing capacity of the facility. As of December 31, 2011, no letters of credit were outstanding. The credit facility requires Entergy Louisiana to maintain a consolidated debt ratio of 65% or less of its total capitalization.

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(e)

Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable. Entergy Mississippi is required to maintain a consolidated debt ratio of 65% or less of its total capitalization.

(f)

The credit facility allows Entergy Texas to issue letters of credit against the borrowing capacity of the facility. As of December 31, 2011, no letters of credit were outstanding. The credit facility requires Entergy Texas to maintain a consolidated debt ratio of 65% or less of its total capitalization. Pursuant to the terms of the credit agreement securitization bonds are excluded from debt and capitalization in calculating the debt ratio.

The facility fees on the credit facilities range from 0.09% to 0.15% of the commitment amount.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through October 31, 2013. In addition to borrowings from commercial banks, these companies are authorized under a FERC order to borrow from the Entergy System money pool. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings. Borrowings from the money pool and external borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2011 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	-
Entergy Gulf States Louisiana	$200	-
Entergy Louisiana	$250	$168
Entergy Mississippi	$175	$2
Entergy New Orleans	$100	-
Entergy Texas	$200	-
System Energy	$200	-

Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy)

See Note 18 to the financial statements for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIE). The variable interest entities have credit facilities and also issue commercial paper to finance the acquisition and ownership of nuclear fuel as follows as of December 31, 2011:

Company	Expiration Date	Amount of Facility	Weighted Average Interest Rate on Borrowings (a)	Amount Outstanding as of December 31, 2011
	(Dollars in Millions)

Entergy Arkansas VIE	July 2013	$85	2.43%	$35.9
Entergy Gulf States Louisiana VIE	July 2013	$85	2.25%	$29.4
Entergy Louisiana VIE	July 2013	$90	2.38%	$44.3
System Energy VIE	July 2013	$100	-	-

(a)	Includes letter of credit fees and bank fronting fees on commercial paper issuances by the VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The VIE for Entergy Gulf States Louisiana does not issue commercial paper, but borrows directly on its bank credit facility.

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The amount outstanding on the Entergy Gulf States Louisiana credit facility is included in long-term debt on its balance sheet and the commercial paper outstanding for the other VIEs is classified as a current liability on the respective balance sheets. The commitment fees on the credit facilities are 0.20% of the undrawn commitment amount. Each credit facility requires the respective lessee (Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, or Entergy Corporation as Guarantor for System Energy) to maintain a consolidated debt ratio of 70% or less of its total capitalization.

The variable interest entities had notes payable that are included in long-term debt on the respective balance sheets as of December 31, 2011 as follows:

Company	Description	Amount

Entergy Arkansas VIE	9% Series H due June 2013	$30 million
Entergy Arkansas VIE	5.69% Series I due July 2014	$70 million
Entergy Arkansas VIE	3.23% Series J due July 2016	$55 million
Entergy Gulf States Louisiana VIE	5.56% Series N due May 2013	$75 million
Entergy Gulf States Louisiana VIE	5.41% Series O due July 2012	$60 million
Entergy Louisiana VIE	5.69% Series E due July 2014	$50 million
Entergy Louisiana VIE	3.30% Series F due March 2016	$20 million
System Energy VIE	6.29% Series F due September 2013	$70 million
System Energy VIE	5.33% Series G due April 2015	$60 million

In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is included as fuel expense.

In February 2012, System Energy VIE issued $50 million of 4.02% Series H notes due February 2017. System Energy used the proceeds to purchase additional nuclear fuel.

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NOTE 5. LONG - TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Long-term debt for Entergy Corporation and subsidiaries as of December 31, 2011 and 2010 consisted of:

Type of Debt and Maturity	Weighted Average Interest Rate December 31, 2011	Interest Rate Ranges at December 31,		Outstanding at December 31,
Type of Debt and Maturity	Weighted Average Interest Rate December 31, 2011	2011	2010	2011	2010
				(In Thousands)

Mortgage Bonds
2011-2016	4.18%	3.25%-6.20%	3.6%-6.2%	$865,000	$920,000
2017-2021	5.40%	3.75%-7.13%	3.75%-7.125%	2,435,000	2,160,000
2022-2026	5.27%	4.44%-5.66%	4.44%-5.66%	1,158,449	1,158,738
2027-2036	6.18%	5.65%-6.40%	5.65%-6.4%	868,145	868,546
2039-2051	6.22%	5.75%-7.88%	5.75%-7.875%	905,000	755,000

Governmental Bonds (a)
2011-2016	3.67%	2.88%-5.80%	2.875%-6.75%	42,795	90,135
2017-2021	4.83%	4.60%-5.00%	4.6%-5.0%	99,700	99,700
2022-2026	5.82%	4.60%-6.20%	4.6%-6.2%	415,005	455,005
2027-2030	5.00%	5.0%	5.0%	198,680	198,680

Securitization Bonds
2013-2020	4.05%	2.12%-5.79%	2.12%-5.79%	416,899	474,318
2021-2023	3.65%	2.04%-5.93%	2.30%-5.93%	653,948	457,100

Variable Interest Entities Notes Payable (Note 4)
2012-2016	4.96%	2.25%-9.00%	2.125%-9%	519,400	474,200

Entergy Corporation Notes
due March 2011	n/a	-	7.06%	-	86,000
due September 2015	n/a	3.625%	3.625%	550,000	550,000
due September 2020	n/a	5.125%	5.125%	450,000	450,000

Note Payable to NYPA	(b)	(b)	(b)	133,363	155,971
5 Year Credit Facility (Note 4)	n/a	0.75%	0.78%	1,920,000	1,632,120
Long-term DOE Obligation (c)	-	-	-	181,031	180,919
Waterford 3 Lease Obligation (d)	n/a	7.45%	7.45%	188,255	223,802
Grand Gulf Lease Obligation (d)	n/a	5.13%	5.13%	178,784	222,280
Bank Credit Facility – Entergy Louisiana	n/a	0.67%	-	50,000	-
Unamortized Premium and Discount - Net				(9,531)	(10,181)
Other				16,523	14,372
Total Long-Term Debt				12,236,446	11,616,705
Less Amount Due Within One Year				2,192,733	299,548
Long-Term Debt Excluding Amount Due Within One Year				$10,043,713	$11,317,157

Fair Value of Long-Term Debt (e)				$12,176,251	$10,988,646

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(a)	Consists of pollution control revenue bonds and environmental revenue bonds.
(b)	These notes do not have a stated interest rate, but have an implicit interest rate of 4.8%.
(c)	Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt.
(d)	See Note 10 for further discussion of the Waterford 3 and Grand Gulf Lease Obligations.
(e)	The fair value excludes lease obligations of $188 million at Entergy Louisiana and $179 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $133 million at Entergy, and includes debt due within one year. Fair values are based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.

The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2011, for the next five years are as follows:

	Amount
	(In Thousands)

2012	$2,124,679
2013	$707,684
2014	$135,899
2015	$860,566
2016	$344,850

In November 2000, Entergy’s non-utility nuclear business purchased the FitzPatrick and Indian Point 3 power plants in a seller-financed transaction. Entergy issued notes to NYPA with seven annual installments of approximately $108 million commencing one year from the date of the closing, and eight annual installments of $20 million commencing eight years from the date of the closing. These notes do not have a stated interest rate, but have an implicit interest rate of 4.8%. In accordance with the purchase agreement with NYPA, the purchase of Indian Point 2 in 2001 resulted in Entergy becoming liable to NYPA for an additional $10 million per year for 10 years, beginning in September 2003. This liability was recorded upon the purchase of Indian Point 2 in September 2001, and is included in the note payable to NYPA balance above. In July 2003, a payment of $102 million was made prior to maturity on the note payable to NYPA. Under a provision in a letter of credit supporting these notes, if certain of the Utility operating companies or System Energy were to default on other indebtedness, Entergy could be required to post collateral to support the letter of credit.

Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through July 2013. Entergy Arkansas has obtained long-term financing authorization from the APSC that extends through December 2012. Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through July 2012.

Capital Funds Agreement

Pursuant to an agreement with certain creditors, Entergy Corporation has agreed to supply System Energy with sufficient capital to:

·	maintain System Energy’s equity capital at a minimum of 35% of its total capitalization (excluding short-term debt);

·	permit the continued commercial operation of Grand Gulf;

·	pay in full all System Energy indebtedness for borrowed money when due; and

·	enable System Energy to make payments on specific System Energy debt, under supplements to the agreement assigning System Energy’s rights in the agreement as security for the specific debt.

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Long-term debt for the Registrant Subsidiaries as of December 31, 2011 and 2010 consisted of:

	2011	2010
	(In Thousands)
Entergy Arkansas
Mortgage Bonds:
5.40% Series due August 2013	$300,000	$300,000
5.0% Series due July 2018	115,000	115,000
3.75% Series due February 2021	350,000	350,000
5.66% Series due February 2025	175,000	175,000
5.9% Series due June 2033	100,000	100,000
6.38% Series due November 2034	60,000	60,000
5.75% Series due November 2040	225,000	225,000
Total mortgage bonds	1,325,000	1,325,000

Governmental Bonds (a):
4.6% Series due 2017, Jefferson County (d)	54,700	54,700
5.0% Series due 2021, Independence County (d)	45,000	45,000
Total governmental bonds	99,700	99,700

Variable Interest Entity Notes Payable (Note 4):
5.60% Series G due September 2011	-	35,000
9% Series H due June 2013	30,000	30,000
5.69% Series I due July 2014	70,000	70,000
3.23% Series J due July 2016	55,000	-
Total variable interest entity notes payable	155,000	135,000

Securitization Bonds:
2.30% Series Senior Secured due August 2021	113,792	124,100
Total securitization bonds	113,792	124,100

Other:
Long-term DOE Obligation (b)	181,031	180,919
Unamortized Premium and Discount – Net	(733)	(812)
Other	2,131	3

Total Long-Term Debt	1,875,921	1,863,910
Less Amount Due Within One Year	-	35,000
Long-Term Debt Excluding Amount Due Within One Year	$1,875,921	$1,828,910

Fair Value of Long-Term Debt (c)	$1,756,361	$1,712,663

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	2011	2010
	(In Thousands)
Entergy Gulf States Louisiana
Mortgage Bonds:
6.0% Series due May 2018	$375,000	$375,000
3.95% Series due October 2020	250,000	250,000
5.59% Series due October 2024	300,000	300,000
6.2% Series due July 2033	240,000	240,000
6.18% Series due March 2035	85,000	85,000
Total mortgage bonds	1,250,000	1,250,000

Governmental Bonds (a):
6.75% Series due 2012, Calcasieu Parish	-	26,170
6.7% Series due 2013, Pointe Coupee Parish	-	9,460
5.7% Series due 2014, Iberville Parish	-	11,710
2.875% Series due 2015, Louisiana Public Facilities Authority (d)	31,955	31,955
5.8% Series due 2016, West Feliciana Parish	10,840	10,840
5.0% Series due 2028, Louisiana Public Facilities Authority (d)	83,680	83,680
Total governmental bonds	126,475	173,815

Variable Interest Entity Notes Payable (Note 4):
5.41% Series O due July 2012	60,000	60,000
5.56% Series N due May 2013	75,000	75,000
Credit Facility due July 2013, weighted avg rate 2.25%	29,400	24,200
Total variable interest entity notes payable	164,400	159,200

Other:
Unamortized Premium and Discount - Net	(2,048)	(2,287)
Other	3,603	3,604

Total Long-Term Debt	1,542,430	1,584,332
Less Amount Due Within One Year	60,000	-
Long-Term Debt Excluding Amount Due Within One Year	$1,482,430	$1,584,332

Fair Value of Long-Term Debt (c)	$1,642,388	$1,643,514

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	2011	2010
	(In Thousands)
Entergy Louisiana
Mortgage Bonds:
6.50% Series due September 2018	$300,000	$300,000
4.8% Series due May 2021	200,000	-
5.40% Series due November 2024	400,000	400,000
4.44% Series due January 2026	250,000	250,000
6.4% Series due October 2034	70,000	70,000
6.3% Series due September 2035	100,000	100,000
6.0% Series due March 2040	150,000	150,000
5.875% Series due June 2041	150,000	150,000
Total mortgage bonds	1,620,000	1,420,000

Governmental Bonds (a):
5.0% Series due 2030, Louisiana Public Facilities Authority (d)	115,000	115,000
Total governmental bonds	115,000	115,000

Variable Interest Entity Notes Payable (Note 4):
5.69% Series E due July 2014	50,000	50,000
3.30% Series F due March 2016	20,000	-
Total variable interest entity notes payable	70,000	50,000

Securitization Bonds:
2.04% Series Senior Secured due June 2021	207,156	-
Total securitization bonds	207,156	-

Other:
Waterford 3 Lease Obligation 7.45% (Note 10)	188,255	223,802
Bank Credit Facility, weighted average rate 0.67% (Note 4)	50,000	-
Unamortized Premium and Discount - Net	(1,912)	(1,689)
Other	3,813	3

Total Long-Term Debt	2,252,312	1,807,116
Less Amount Due Within One Year	75,309	35,550
Long-Term Debt Excluding Amount Due Within One Year	$2,177,003	$1,771,566

Fair Value of Long-Term Debt (c)	$2,211,355	$1,515,121

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	2011	2010
	(In Thousands)
Entergy Mississippi
Mortgage Bonds:
4.65% Series due May 2011	$-	$80,000
5.15% Series due February 2013	100,000	100,000
5.92% Series due February 2016	-	100,000
3.25% Series due June 2016	125,000	-
4.95% Series due June 2018	95,000	95,000
6.64% Series due July 2019	150,000	150,000
6.0% Series due November 2032	75,000	75,000
6.25% Series due April 2034	100,000	100,000
6.20% Series due April 2040	80,000	80,000
6.0% Series due May 2051	150,000	-
Total mortgage bonds	875,000	780,000

Governmental Bonds (a):
4.60% Series due 2022, Mississippi Business Finance Corp.(d)	16,030	16,030
4.90% Series due 2022, Independence County (d)	30,000	30,000
Total governmental bonds	46,030	46,030

Other:
Unamortized Premium and Discount - Net	(591)	(652)

Total Long-Term Debt	920,439	825,378
Less Amount Due Within One Year	-	80,000
Long-Term Debt Excluding Amount Due Within One Year	$920,439	$745,378

Fair Value of Long-Term Debt (c)	$985,600	$802,045

	2011	2010
	(In Thousands)
Entergy New Orleans
Mortgage Bonds:
5.25% Series due August 2013	$70,000	$70,000
5.10% Series due December 2020	25,000	25,000
5.6% Series due September 2024	33,449	33,738
5.65% Series due September 2029	38,145	38,546
Total mortgage bonds	166,594	167,284

Other:
Unamortized Premium and Discount - Net	(57)	(69)

Total Long-Term Debt	166,537	167,215
Less Amount Due Within One Year	-	-
Long-Term Debt Excluding Amount Due Within One Year	$166,537	$167,215

Fair Value of Long-Term Debt (c)	$169,270	$171,077

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	2011	2010
	(In Thousands)
Entergy Texas
Mortgage Bonds:
3.60% Series due June 2015	$200,000	$200,000
7.125% Series due February 2019	500,000	500,000
4.1% Series due September 2021	75,000	-
7.875% Series due June 2039	150,000	150,000
Total mortgage bonds	925,000	850,000

Securitization Bonds:
5.51% Series Senior Secured, Series A due October 2013	18,494	38,152
5.79% Series Senior Secured, Series A due October 2018	121,600	121,600
5.93% Series Senior Secured, Series A due June 2022	114,400	114,400
2.12% Series Senior Secured due February 2016	132,005	169,766
3.65% Series Senior Secured due August 2019	144,800	144,800
4.38% Series Senior Secured due November 2023	218,600	218,600
Total securitization bonds	749,899	807,318

Other:
Unamortized Premium and Discount - Net	(3,103)	(3,419)
Other	5,331	5,331

Total Long-Term Debt	1,677,127	1,659,230
Less Amount Due Within One Year	-	-
Long-Term Debt Excluding Amount Due Within One Year	$1,677,127	$1,659,230

Fair Value of Long-Term Debt (c)	$1,906,081	$1,822,219

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	2011	2010
	(In Thousands)
System Energy
Mortgage Bonds:
6.2% Series due October 2012	$70,000	$70,000
Total mortgage bonds	70,000	70,000

Governmental Bonds (a):
5.875% Series due 2022, Mississippi Business Finance Corp.	216,000	216,000
5.9% Series due 2022, Mississippi Business Finance Corp.	102,975	102,975
6.2% Series due 2026, Claiborne County	50,000	90,000
Total governmental bonds	368,975	408,975

Variable Interest Entity Notes Payable (Note 4):
6.29% Series F due September 2013	70,000	70,000
5.33% Series G due April 2015	60,000	60,000
Total variable interest entity notes payable	130,000	130,000

Other:
Grand Gulf Lease Obligation 5.13% (Note 10)	178,784	222,280
Unamortized Premium and Discount - Net	(714)	(789)
Other	3	2

Total Long-Term Debt	747,048	830,468
Less Amount Due Within One Year	110,163	33,740
Long-Term Debt Excluding Amount Due Within One Year	$636,885	$796,728

Fair Value of Long-Term Debt (c)	$582,952	$611,837

(a)	Consists of pollution control revenue bonds and environmental revenue bonds.
(b)	Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt.
(c)	The fair value excludes lease obligations of $188 million at Entergy Louisiana and $179 million at System Energy and long-term DOE obligations of $181 million at Entergy Arkansas, and includes debt due within one year. Fair values are based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.
(d)	The bonds are secured by a series of collateral first mortgage bonds.

The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt outstanding as of December 31, 2011, for the next five years are as follows:

	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy

2012	-	$60,000	$50,000	-	-	-	$70,000
2013	$330,000	$104,400	-	$100,000	$70,000	$18,494	$70,000
2014	$70,000	-	$50,000	-	-	-	-
2015	-	$31,955	-	-	-	$200,000	$60,000
2016	$55,000	$10,840	$20,000	$125,000	-	$132,005	-

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Entergy Corporation Debt Issuance

In January 2012, Entergy Corporation issued $500 million of 4.70% senior notes due January 2017. Entergy Corporation used the proceeds to repay borrowings under its $3.5 billion credit facility.

Entergy Louisiana Debt Issuances

On December 14, 2011, Entergy Louisiana issued $750 million of 1.1007% Series first mortgage bonds, due December 31, 2012, to Entergy Corporation. Entergy Louisiana repurchased the bonds at par, plus accrued interest of $161 thousand, on December 22, 2011.

Entergy Arkansas Securitization Bonds

In June 2010 the APSC issued a financing order authorizing the issuance of bonds to recover Entergy Arkansas’s January 2009 ice storm damage restoration costs, including carrying costs of $11.5 million and $4.6 million of up-front financing costs. In August 2010, Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, issued $124.1 million of storm cost recovery bonds. The bonds have a coupon of 2.30% and an expected maturity date of August 2021. Although the principal amount is not due until the date given above, Entergy Arkansas Restoration Funding expects to make principal payments on the bonds over the next five years in the amount of $12.2 million for 2012, $12.6 million for 2013, $12.8 million for 2014, $13.2 million for 2015, and $13.4 million for 2016. With the proceeds, Entergy Arkansas Restoration Funding purchased from Entergy Arkansas the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy Arkansas balance sheet. The creditors of Entergy Arkansas do not have recourse to the assets or revenues of Entergy Arkansas Restoration Funding, including the storm recovery property, and the creditors of Entergy Arkansas Restoration Funding do not have recourse to the assets or revenues of Entergy Arkansas. Entergy Arkansas has no payment obligations to Entergy Arkansas Restoration Funding except to remit storm recovery charge collections.

Entergy Louisiana Securitization Bonds – Little Gypsy

In August 2011, the LPSC issued a financing order authorizing the issuance of bonds to recover Entergy Louisiana’s investment recovery costs associated with the cancelled Little Gypsy repowering project. In September 2011, Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, issued $207.2 million of senior secured investment recovery bonds. The bonds have an interest rate of 2.04% and an expected maturity date of June 2021. Although the principal amount is not due until the date given above, Entergy Louisiana Investment Recovery Funding expects to make principal payments on the bonds over the next five years in the amounts of $25.6 million for 2012, $16.6 million for 2013, $21.9 million for 2014, $20.5 million for 2015, and $21.6 million for 2016. With the proceeds, Entergy Louisiana Investment Recovery Funding purchased from Entergy Louisiana the investment recovery property, which is the right to recover from customers through an investment recovery charge amounts sufficient to service the bonds. In accordance with the financing order, Entergy Louisiana will apply the proceeds it received from the sale of the investment recovery property as a reimbursement for previously-incurred investment recovery costs. The investment recovery property is reflected as a regulatory asset on the consolidated Entergy Louisiana balance sheet. The creditors of Entergy Louisiana do not have recourse to the assets or revenues of Entergy Louisiana Investment Recovery Funding, including the investment recovery property, and the creditors of Entergy Louisiana Investment Recovery Funding do not have recourse to the assets or revenues of Entergy Louisiana. Entergy Louisiana has no payment obligations to Entergy Louisiana Investment Recovery Funding except to remit investment recovery charge collections.

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Entergy Texas Securitization Bonds - Hurricane Rita

In April 2007 the PUCT issued a financing order authorizing the issuance of securitization bonds to recover $353 million of Entergy Texas’s Hurricane Rita reconstruction costs and up to $6 million of transaction costs, offset by $32 million of related deferred income tax benefits. In June 2007, Entergy Gulf States Reconstruction Funding I, LLC, a company that is now wholly-owned and consolidated by Entergy Texas, issued $329.5 million of senior secured transition bonds (securitization bonds) as follows:

	Amount
	(In Thousands)
Senior Secured Transition Bonds, Series A:
Tranche A-1 (5.51%) due October 2013	$93,500
Tranche A-2 (5.79%) due October 2018	121,600
Tranche A-3 (5.93%) due June 2022	114,400
Total senior secured transition bonds	$329,500

Although the principal amount of each tranche is not due until the dates given above, Entergy Gulf States Reconstruction Funding expects to make principal payments on the bonds over the next five years in the amounts of $20.8 million for 2012, $21.9 million for 2013, $23.2 million for 2014, $24.6 million for 2015, and $26.0 million for 2016. Of the scheduled principal payments for 2012, $18.5 million are for Tranche A-1 and $2.3 million are for Tranche A-2, and all of the scheduled principal payments for 2013-2016 are for Tranche A-2.

With the proceeds, Entergy Gulf States Reconstruction Funding purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Gulf States Reconstruction Funding, including the transition property, and the creditors of Entergy Gulf States Reconstruction Funding do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Gulf States Reconstruction Funding except to remit transition charge collections.

Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav

In September 2009 the PUCT authorized the issuance of securitization bonds to recover $566.4 million of Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs, plus carrying costs and transaction costs, offset by insurance proceeds. In November 2009, Entergy Texas Restoration funding, LLC (Entergy Texas Restoration Funding), a company wholly-owned and consolidated by Entergy Texas, issued $545.9 million of senior secured transition bonds (securitization bonds), as follows:

	Amount
	(In Thousands)
Senior Secured Transition Bonds
Tranche A-1 (2.12%) due February 2016	$182,500
Tranche A-2 (3.65%) due August 2019	144,800
Tranche A-3 (4.38%) due November 2023	218,600
Total senior secured transition bonds	$545,900

Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding expects to make principal payments on the bonds over the next five years in the amount of $38.6 million for 2012, $39.4 million for 2013, $40.2 million for 2014, $41.2 million for 2015, and $42.6 million for 2016. All of the scheduled principal payments for 2012-2014 are for Tranche A-1, $13.8 million of the scheduled principal payments for 2015 are for Tranche A-1 and $27.4 million are for Tranche A-2, and all of the scheduled principal payments for 2016 are for Tranche A-2.

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With the proceeds, Entergy Texas Restoration Funding purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding, including the transition property, and the creditors of Entergy Texas Restoration Funding do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding except to remit transition charge collections.

Entergy New Orleans Affiliate Notes

Pursuant to its plan of reorganization, in May 2007 Entergy New Orleans issued notes due in three years in satisfaction of its affiliate prepetition accounts payable (approximately $74 million, including interest), including its indebtedness to the Entergy System money pool. In May 2010, Entergy New Orleans repaid, at maturity, the notes payable.

NOTE 6. PREFERRED EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans)

The number of shares and units authorized and outstanding and dollar value of preferred stock, preferred membership interests, and minority interest for Entergy Corporation subsidiaries as of December 31, 2011 and 2010 are presented below. All series of the Utility preferred stock are redeemable at the option of the related company.

	Shares/Units Authorized		Shares/Units Outstanding
	2011	2010	2011	2010	2011	2010
Entergy Corporation					(Dollars in Thousands)
Utility:
Preferred Stock or Preferred Membership Interests without sinking fund:
Entergy Arkansas, 4.32%-6.45% Series	3,413,500	3,413,500	3,413,500	3,413,500	$116,350	$116,350
Entergy Gulf States Louisiana, Series A 8.25 %	100,000	100,000	100,000	100,000	10,000	10,000
Entergy Louisiana, 6.95% Series (a)	1,000,000	1,000,000	840,000	840,000	84,000	84,000
Entergy Mississippi, 4.36%-6.25% Series	1,403,807	1,403,807	1,403,807	1,403,807	50,381	50,381
Entergy New Orleans, 4.36%-5.56% Series	197,798	197,798	197,798	197,798	19,780	19,780
Total Utility Preferred Stock or Preferred Membership Interests without sinking fund	6,115,105	6,115,105	5,955,105	5,955,105	280,511	280,511

Entergy Wholesale Commodities:
Preferred Stock without sinking fund:
Entergy Asset Management, 8.95% rate (b)	1,000,000	1,000,000	-	305,240	-	29,375
Other	-	-	-	-	-	852
Total Subsidiaries’ Preferred Stock without sinking fund	7,115,105	7,115,105	5,955,105	6,260,345	$280,511	$310,738

(a)	In 2007, Entergy Louisiana Holdings, an Entergy subsidiary, purchased 160,000 of these shares from the holders.

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(b)

Upon the sale of Class B preferred shares in December 2009, Entergy Asset Management had issued and outstanding Class A and Class B preferred shares. On December 20, 2011, Entergy Asset Management purchased all of the outstanding Class B preferred shares from the holder thereof; currently, there are no outstanding Class B preferred shares. On December 20, 2011, Entergy Asset Management purchased all of the outstanding Class A preferred shares (278,905 shares) that were held by a third party; currently, there are 4,759 shares held by an Entergy affiliate.

At December 31, 2011 and 2010, Entergy Gulf States Louisiana had outstanding 100,000 units of no par value 8.25% Series Preferred Membership Interests that were initially issued by Entergy Gulf States, Inc. as preference stock. The preference shares were converted into the preferred units as part of the jurisdictional separation. The distributions are cumulative and payable quarterly beginning March 15, 2008. The preferred membership interests are redeemable on or after December 15, 2015, at Entergy Gulf States Louisiana’s option, at the fixed redemption price of $100 per unit.

The number of shares and units authorized and outstanding and dollar value of preferred stock and membership interests for Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans as of December 31, 2011 and 2010 are presented below. All series of the Utility operating companies’ preferred stock and membership interests are redeemable at the respective company’s option at the call prices presented. Dividends and distributions paid on all of Entergy’s preferred stock and membership interests series are eligible for the dividends received deduction. The dividends received deduction is limited by Internal Revenue Code section 244 for the following preferred stock series: Entergy Arkansas 4.72%, Entergy Mississippi 4.56%, and Entergy New Orleans 4.75%.

	Shares Authorized and Outstanding		Dollars (In Thousands)		Call Price per Share as of December 31,
	2011	2010	2011	2010	2011
Entergy Arkansas Preferred Stock
Without sinking fund:
Cumulative, $100 par value:
4.32% Series	70,000	70,000	$7,000	$7,000	$103.65
4.72% Series	93,500	93,500	9,350	9,350	$107.00
4.56% Series	75,000	75,000	7,500	7,500	$102.83
4.56% 1965 Series	75,000	75,000	7,500	7,500	$102.50
6.08% Series	100,000	100,000	10,000	10,000	$102.83
Cumulative, $25 par value:
6.45% Series (a)	3,000,000	3,000,000	75,000	75,000	$-
Total without sinking fund	3,413,500	3,413,500	$116,350	$116,350

	Units Authorized and Outstanding		Dollars (In Thousands)		Call Price per Unit as of December 31,
	2011	2010	2011	2010	2011
Entergy Gulf States Louisiana Preferred Membership Interests
Without sinking fund:
Cumulative, $100 liquidation value:
8.25% Series (b)	100,000	100,000	$10,000	$10,000	$-
Total without sinking fund	100,000	100,000	$10,000	$10,000

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	Units Authorized and Outstanding		Dollars (In Thousands)		Call Price per Unit as of December 31,
	2011	2010	2011	2010	2011
Entergy Louisiana Preferred Membership Interests
Without sinking fund:
Cumulative, $100 liquidation value:
6.95% Series (c)	1,000,000	1,000,000	$100,000	$100,000	$-
Total without sinking fund	1,000,000	1,000,000	$100,000	$100,000

	Shares Authorized and Outstanding		Dollars (In Thousands)		Call Price per Share as of December 31,
	2011	2010	2011	2010	2011
Entergy Mississippi Preferred Stock
Without sinking fund:
Cumulative, $100 par value:
4.36% Series	59,920	59,920	$5,992	$5,992	$103.88
4.56% Series	43,887	43,887	4,389	4,389	$107.00
4.92% Series	100,000	100,000	10,000	10,000	$102.88
Cumulative, $25 par value
6.25% Series (d)	1,200,000	1,200,000	30,000	30,000	$-
Total without sinking fund	1,403,807	1,403,807	$50,381	$50,381

	Shares Authorized and Outstanding		Dollars (In Thousands)		Call Price per Share as of December 31,
	2011	2010	2011	2010	2011
Entergy New Orleans Preferred Stock
Without sinking fund:
Cumulative, $100 par value:
4.36% Series	60,000	60,000	$6,000	$6,000	$104.58
4.75% Series	77,798	77,798	7,780	7,780	$105.00
5.56% Series	60,000	60,000	6,000	6,000	$102.59
Total without sinking fund	197,798	197,798	$19,780	$19,780

(a)	Series is callable at par.
(b)	Series is callable at par on and after December 15, 2015.
(c)	Series is callable at par.
(d)	Series is callable at par.

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NOTE 7. COMMON EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Common Stock

Common stock and treasury stock shares activity for Entergy for 2011, 2010, and 2009 is as follows:

	2011		2010		2009
	Common Shares Issued	Treasury Shares	Common Shares Issued	Treasury Shares	Common Shares Issued	Treasury Shares

Beginning Balance, January 1	254,752,788	76,006,920	254,752,788	65,634,580	248,174,087	58,815,518
Equity Unit Transaction	-	-	-	-	6,578,701	-
Repurchases	-	3,475,000	-	11,490,551	-	7,680,000
Issuances:
Employee Stock-Based Compensation Plans	-	(1,079,008)	-	(1,113,411)	-	(856,390)
Directors’ Plan	-	(5,924)	-	(4,800)	-	(4,548)
Ending Balance, December 31	254,752,788	78,396,988	254,752,788	76,006,920	254,752,788	65,634,580

In December 2005, Entergy Corporation sold 10 million equity units with a stated amount of $50 each. An equity unit consisted of (1) a note, initially due February 2011 and initially bearing interest at an annual rate of 5.75%, and (2) a purchase contract that obligated the holder of the equity unit to purchase for $50 between 0.5705 and 0.7074 shares of Entergy Corporation common stock on or before February 17, 2009. Entergy paid the holders quarterly contract adjustment payments of 1.875% per year on the stated amount of $50 per equity unit. Under the terms of the purchase contracts, Entergy attempted to remarket the notes in February 2009 but was unsuccessful, the note holders put the notes to Entergy, Entergy retired the notes, and Entergy issued shares of common stock to settle the purchase contracts.

Entergy Corporation reissues treasury shares to meet the requirements of the Stock Plan for Outside Directors (Directors’ Plan), two Equity Ownership Plans of Entergy Corporation and Subsidiaries, the Equity Awards Plan of Entergy Corporation and Subsidiaries, and certain other stock benefit plans. The Directors’ Plan awards to non-employee directors a portion of their compensation in the form of a fixed number of shares of Entergy Corporation common stock.

In January 2007, the Board approved a repurchase program that authorized Entergy to repurchase up to $1.5 billion of its common stock. In January 2008, the Board authorized an incremental $500 million share repurchase program to enable Entergy to consider opportunistic purchases in response to equity market conditions. Entergy completed both the $1.5 billion and $500 million programs in the third quarter 2009. In October 2009, the Board granted authority for an additional $750 million share repurchase program which was completed in the fourth quarter 2010. In October 2010, the Board granted authority for an additional $500 million share repurchase program. As of December 31, 2011, $350 million remains under the $500 million share repurchase program.

Retained Earnings and Dividend Restrictions

Provisions within the articles of incorporation or pertinent indentures and various other agreements relating to the long-term debt and preferred stock of certain of Entergy Corporation’s subsidiaries could restrict the payment of cash dividends or other distributions on their common and preferred equity. As of December 31, 2011, under provisions in their mortgage indentures, Entergy Arkansas and Entergy Mississippi had retained earnings

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unavailable for distribution to Entergy Corporation of $394.9 million and $68.5 million, respectively. Entergy Corporation received dividend payments from subsidiaries totaling $595 million in 2011, $580 million in 2010, and $417 million in 2009.

Comprehensive Income

Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy, Entergy Gulf States Louisiana, and Entergy Louisiana. Accumulated other comprehensive income (loss) in the balance sheets included the following components:

	Entergy		Entergy Gulf States Louisiana		Entergy Louisiana
	December 31, 2011	December 31, 2010	December 31, 2011	December 31, 2010	December 31, 2011	December 31, 2010
	(In Thousands)

Cash flow hedges net unrealized gain	$177,497	$106,258	$-	$-	$-	$-
Pension and other postretirement liabilities	(499,556)	(276,466)	(69,610)	(40,304)	(39,507)	(24,962)
Net unrealized investment gains	150,939	129,685	-	-	-	-
Foreign currency translation	2,668	2,311	-	-	-	-
Total	($168,452)	($38,212)	($69,610)	($40,304)	($39,507)	($24,962)

Other comprehensive income and total comprehensive income for years ended December 31, 2011, 2010, and 2009 are presented in Entergy’s, Entergy Gulf States Louisiana’s, and Entergy Louisiana’s Statements of Comprehensive Income.

NOTE 8. COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While management is unable to predict the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements.

Vidalia Purchased Power Agreement

Entergy Louisiana has an agreement extending through the year 2031 to purchase energy generated by a hydroelectric facility known as the Vidalia project. Entergy Louisiana made payments under the contract of approximately $185.6 million in 2011, $216.5 million in 2010, and $204.9 million in 2009. If the maximum percentage (94%) of the energy is made available to Entergy Louisiana, current production projections would require estimated payments of approximately $172.1 million in 2012, and a total of $2.5 billion for the years 2013 through 2031. Entergy Louisiana currently recovers the costs of the purchased energy through its fuel adjustment clause.

In an LPSC-approved settlement related to tax benefits from the tax treatment of the Vidalia contract, Entergy Louisiana agreed to credit rates by $11 million each year for up to ten years, beginning in October 2002. In addition, in accordance with an LPSC settlement, Entergy Louisiana credited rates in August 2007 by $11.3 million (including interest) as a result of a settlement with the IRS of the 2001 tax treatment of the Vidalia contract. As

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discussed in more detail in Note 3 to the financial statements, in August 2011, Entergy agreed to a settlement with the IRS regarding the mark-to-market income tax treatment of various wholesale electric power purchase and sale agreements, including the Vidalia agreement. In October 2011, the LPSC approved a final settlement under which Entergy Louisiana agreed to share the remaining benefits of this tax accounting election by crediting customers an additional $20.235 million per year for 15 years beginning January 2012. Entergy Louisiana recorded a $199 million regulatory charge and a corresponding net-of-tax regulatory liability to reflect this obligation. The provisions of the settlement also provide that the LPSC shall not recognize or use Entergy Louisiana’s use of the cash benefits from the tax treatment in setting any of Entergy Louisiana’s rates. Therefore, to the extent Entergy Louisiana’s use of the proceeds would ordinarily have reduced its rate base, no change in rate base shall be reflected for ratemaking purposes.

Nuclear Insurance

Third Party Liability Insurance

1.	The primary level is private insurance underwritten by American Nuclear Insurers (ANI) and provides public liability insurance coverage of $375 million. If this amount is not sufficient to cover claims arising from an accident, the second level, Secondary Financial Protection, applies.

Within the Secondary Financial Protection level, each nuclear reactor has a contingent obligation to pay a retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless of proximity to the incident or fault, up to a maximum of $117.5 million per reactor per incident (Entergy’s maximum total contingent obligation per incident is $1.3 billion). This consists of a $111.9 million maximum retrospective premium plus a five percent surcharge, which equates to $117.5 million, that may be payable, if needed, at a rate that is currently set at $17.5 million per year per incident per nuclear power reactor.

In the event that one or more acts of terrorism cause a nuclear power plant accident, which results in third-party damages – off-site property and environmental damage, off-site bodily injury, and on-site third-party bodily injury (i.e. contractors); the primary level provided by ANI combined with the Secondary Financial Protection would provide $12.6 billion in coverage. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event.

Currently, 104 nuclear reactors are participating in the Secondary Financial Protection program. The product of the maximum retrospective premium assessment to the nuclear power industry and the number of nuclear power reactors provides over $12.2 billion in secondary layer insurance coverage to compensate the public in the event of a nuclear power reactor accident. The Price-Anderson Act provides that all potential liability for a nuclear accident is limited to the amounts of insurance coverage available under the primary and secondary layers.

Entergy Arkansas has two licensed reactors and Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy each have one licensed reactor (10% of Grand Gulf is owned by a non-affiliated company (SMEPA) that would share on a pro-rata basis in any retrospective premium assessment to System Energy under the Price-Anderson Act). The Entergy Wholesale Commodities segment includes the ownership and operation of six nuclear power reactors and the ownership of the shutdown Indian Point 1 reactor and Big Rock Point facility.

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Property Insurance

Entergy’s nuclear owner/licensee subsidiaries are members of Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage, including decontamination and premature decommissioning expense, to the members’ nuclear generating plants. Effective April 1, 2011, Entergy was insured against such losses per the following structures:

Utility Plants (ANO 1 and 2, Grand Gulf, River Bend, and Waterford 3)

·	Primary Layer (per plant) - $500 million per occurrence

·	Excess Layer (per plant) - $750 million per occurrence

·	Blanket Layer (shared among the Utility plants) - $350 million per occurrence

·	Total limit - $1.6 billion per occurrence

·	Deductibles:

·	$2.5 million per occurrence - Turbine/generator damage

·	$2.5 million per occurrence - Other than turbine/generator damage

·	$10 million per occurrence plus 10% of amount above $10 million - Damage from a windstorm, flood, earthquake, or volcanic eruption

Note: ANO 1 and 2 share in the primary and excess layers with common policies because the policies are issued on a per site basis.

Entergy Wholesale Commodities Plants (Indian Point, FitzPatrick, Pilgrim, Vermont Yankee, Palisades, and Big Rock Point)

·	Primary Layer (per plant) - $500 million per occurrence

·	Excess Layer - $615 million per occurrence

·	Total limit - $1.115 billion per occurrence

·	Deductibles:

·	$2.5 million per occurrence - Turbine/generator damage

·	$2.5 million per occurrence - Other than turbine/generator damage

·	$10 million per occurrence plus 10% of amount above $10 million - Damage from a windstorm, flood, earthquake, or volcanic eruption

Note: The Indian Point Units share in the primary and excess layers with common policies because the policies are issued on a per site basis. Big Rock Point has its own primary policy with no excess coverage.

In addition, Waterford 3, Grand Gulf, and the Entergy Wholesale Commodities plants are also covered under NEIL’s Accidental Outage Coverage program. This coverage provides certain fixed indemnities in the event of an unplanned outage that results from a covered NEIL property damage loss, subject to a deductible period. The following summarizes this coverage effective April 1, 2011:

Waterford 3

·	$2.95 million weekly indemnity

·	$413 million maximum indemnity

·	Deductible: 26 week deductible period

Grand Gulf

·	$400,000 weekly indemnity (total for four policies)

·	$56 million maximum indemnity (total for four policies)

·	Deductible: 26 week deductible period

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Indian Point 2, Indian Point 3, and Palisades

·	$4.5 million weekly indemnity

·	$490 million maximum indemnity

·	Deductible: 12 week deductible period

FitzPatrick and Pilgrim

·	$4.0 million weekly indemnity

·	$490 million maximum indemnity

·	Deductible: 12 week deductible period

Vermont Yankee

·	$3.5 million weekly indemnity

·	$435 million maximum indemnity

·	Deductible: 12 week deductible period

Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2011, the maximum amounts of such possible assessments per occurrence were as follows:

		Assessments
		(In Millions)
Utility:
Entergy Arkansas		$20.1
Entergy Gulf States Louisiana		$16.3
Entergy Louisiana		$19.3
Entergy Mississippi		$0.07
Entergy New Orleans		$0.07
Entergy Texas		N/A
System Energy		$16.3

Entergy Wholesale Commodities		$-

Potential assessments for the Entergy Wholesale Commodities plants are covered by insurance obtained through NEIL’s reinsurers.

Entergy maintains property insurance for its nuclear units in excess of the NRC’s minimum requirement of $1.06 billion per site for nuclear power plant licensees. NRC regulations provide that the proceeds of this insurance must be used, first, to render the reactor safe and stable, and second, to complete decontamination operations. Only after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made available for the benefit of plant owners or their creditors.

In the event that one or more acts of terrorism causes property damage under one or more or all nuclear insurance policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate of $3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources applicable to such losses. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event.

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Conventional Property Insurance

Entergy’s conventional property insurance program provides coverage of up to $400 million on an Entergy system-wide basis for all operational perils (direct physical loss or damage due to machinery breakdown, electrical failure, fire, lightning, hail, or explosion) on an “each and every loss” basis; up to $400 million in coverage for certain natural perils (direct physical loss or damage due to earthquake, tsunami, flood, ice storm, and tornado) on an annual aggregate basis; and up to $125 million for certain other natural perils (direct physical loss or damage due to a named windstorm or storm surge) on an annual aggregate basis. The conventional property insurance program provides up to $50 million in coverage for the Entergy New Orleans gas distribution system on an annual aggregate basis. The coverage is subject to a $20 million self-insured retention per occurrence for operational perils and a $35 million self-insured retention per occurrence for natural perils and for the Entergy New Orleans gas distribution system.

Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes above-ground transmission and distribution lines, poles, and towers. The primary layer consists of a $65 million layer in excess of the self-insured retention and the excess layer consists of a $335 million layer in excess of the $65 million primary layer. Both layers are placed on a quota share basis through several insurers. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries, including the owners of the nuclear power plants in the Entergy Wholesale Commodities segment. Entergy also, purchases $300 million in terrorism insurance coverage for its conventional property. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event.

In addition to the conventional property insurance program, Entergy has purchased additional coverage ($20 million per occurrence) for some of its non-regulated, non-generation assets. This policy serves to buy-down the $20 million deductible and is placed on a scheduled location basis. The applicable deductibles are $100,000 to $250,000, except for properties that are damaged by flooding and properties whose values are greater than $20 million; these properties have a $500,000 deductible.

Gas System Rebuild Insurance Proceeds (Entergy New Orleans)

Entergy New Orleans received insurance proceeds for future construction expenditures associated with rebuilding its gas system, and the October 2006 City Council resolution approving the settlement of Entergy New Orleans’s rate and storm-cost recovery filings requires Entergy New Orleans to record those proceeds in a designated sub-account of other deferred credits until the proceeds are spent on the rebuild project. This other deferred credit is shown as “Gas system rebuild insurance proceeds” on Entergy New Orleans’s balance sheet.

Employment and Labor-related Proceedings

The Registrant Subsidiaries and other Entergy subsidiaries are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees and third parties not selected for open positions. These actions include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board; claims of retaliation; and claims for or regarding benefits under various Entergy Corporation sponsored plans. Entergy and the Registrant Subsidiaries are responding to these suits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Utility operating companies.

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Asbestos Litigation (Entergy Gulf States Louisiana, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

Numerous lawsuits have been filed in federal and state courts primarily in Texas and Louisiana, primarily by contractor employees who worked in the 1940-1980s timeframe, against Entergy Gulf States Louisiana and Entergy Texas, and to a lesser extent the other Utility operating companies, as premises owners of power plants, for damages caused by alleged exposure to asbestos. Many other defendants are named in these lawsuits as well. Currently, there are approximately 500 lawsuits involving approximately 5,000 claimants. Management believes that adequate provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of the Utility operating companies.

Grand Gulf - Related Agreements

Capital Funds Agreement (Entergy Corporation and System Energy)

System Energy has entered into agreements with Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans whereby they are obligated to purchase their respective entitlements of capacity and energy from System Energy’s interest in Grand Gulf, and to make payments that, together with other available funds, are adequate to cover System Energy’s operating expenses. System Energy would have to secure funds from other sources, including Entergy Corporation’s obligations under the Capital Funds Agreement, to cover any shortfalls from payments received from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans under these agreements.

Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas-36%, Entergy Louisiana-14%, Entergy Mississippi-33%, and Entergy New Orleans-17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. The agreement will remain in effect until terminated by the parties and the termination is approved by the FERC, most likely upon Grand Gulf’s retirement from service. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2011 under the agreement are approximately $17.2 million for Entergy Arkansas, $6.9 million for Entergy Louisiana, $14.4 million for Entergy Mississippi, and $8.4 million for Entergy New Orleans.

Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas-17.1%, Entergy Louisiana-26.9%, Entergy Mississippi-31.3%, and Entergy New Orleans-24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including an amount sufficient to amortize the cost of Grand Gulf 2 over 27 years (See Reallocation Agreement terms below) and expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement have exceeded the amounts payable under the Availability Agreement. Accordingly, no payments under the Availability Agreement have ever been required. If Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments.

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Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. FERC’s decision allocating a portion of Grand Gulf capacity and energy to Entergy Arkansas supersedes the Reallocation Agreement as it relates to Grand Gulf. Responsibility for any Grand Gulf 2 amortization amounts has been individually allocated (Entergy Louisiana-26.23%, Entergy Mississippi-43.97%, and Entergy New Orleans-29.80%) under the terms of the Reallocation Agreement. However, the Reallocation Agreement does not affect Entergy Arkansas’s obligation to System Energy’s lenders under the assignments referred to in the preceding paragraph. Entergy Arkansas would be liable for its share of such amounts if Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans were unable to meet their contractual obligations. No payments of any amortization amounts will be required so long as amounts paid to System Energy under the Unit Power Sales Agreement, including other funds available to System Energy, exceed amounts required under the Availability Agreement, which is expected to be the case for the foreseeable future.

Reimbursement Agreement (System Energy)

In December 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million. The interests represent approximately 11.5% of Grand Gulf. During the term of the leases, System Energy is required to maintain letters of credit for the equity investors to secure certain amounts payable to the equity investors under the transactions.

Under the provisions of the reimbursement agreement relating to the letters of credit, System Energy has agreed to a number of covenants regarding the maintenance of certain capitalization and fixed charge coverage ratios. System Energy agreed, during the term of the reimbursement agreement, to maintain a ratio of debt to total liabilities and equity less than or equal to 70%. In addition, System Energy must maintain, with respect to each fiscal quarter during the term of the reimbursement agreement, a ratio of adjusted net income to interest expense of at least 1.50 times earnings. As of December 31, 2011, System Energy was in compliance with these covenants.

NOTE 9. ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Accounting standards require the recording of liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of those assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning line item on the balance sheets.

These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries.

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In accordance with ratemaking treatment and as required by regulatory accounting standards, the depreciation provisions for the Registrant Subsidiaries include a component for removal costs that are not asset retirement obligations under accounting standards. In accordance with regulatory accounting principles, the Registrant Subsidiaries have recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between estimated incurred removal costs and estimated removal costs recovered in rates:

	December 31,
	2011	2010
	(In Millions)

Entergy Arkansas	($16.4)	($24.0)
Entergy Gulf States Louisiana	($30.3)	($24.9)
Entergy Louisiana	($62.6)	($52.9)
Entergy Mississippi	$48.5	$46.1
Entergy New Orleans	$16.3	$15.4
Entergy Texas	$4.5	$7.3
System Energy	$11.8	$12.2

The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2011 by Entergy were as follows:

	Liabilities as of December 31, 2010	Accretion	Change in Cash Flow Estimate	Spending	Liabilities as of December 31, 2011
			(In Millions)
Utility:
Entergy Arkansas	$602.2	$38.0	$-	$-	$640.2
Entergy Gulf States Louisiana	$339.9	$19.9	$-	$-	$359.8
Entergy Louisiana	$321.2	$24.6	$-	$-	$345.8
Entergy Mississippi	$5.4	$0.3	$-	$-	$5.7
Entergy New Orleans	$3.4	$0.2	$-	($0.7)	$2.9
Entergy Texas	$3.6	$0.3	$-	$-	$3.9
System Energy	$452.8	$31.5	($38.9)	$-	$445.4

Entergy Wholesale Commodities	$1,420.0	$115.6	($34.1)	($8.6)	$1,492.9

The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2010 by Entergy were as follows:

	Liabilities as of December 31, 2009	Accretion	Change in Cash Flow Estimate	Spending	Liabilities as of December 31, 2010
			(In Millions)
Utility:
Entergy Arkansas	$566.4	$35.8	$-	$-	$602.2
Entergy Gulf States Louisiana	$321.2	$18.7	$-	$-	$339.9
Entergy Louisiana	$298.2	$23.0	$-	$-	$321.2
Entergy Mississippi	$5.1	$0.3	$-	$-	$5.4
Entergy New Orleans	$3.2	$0.2	$-	$-	$3.4
Entergy Texas	$3.4	$0.2	$-	$-	$3.6
System Energy	$421.4	$31.4	$-	$-	$452.8

Entergy Wholesale Commodities	$1,320.6	$107.6	$-	($8.2)	$1,420.0

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Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may vary from the estimates because of regulatory requirements, changes in technology, and increased costs of labor, materials, and equipment. As described below, during 2011 Entergy updated decommissioning cost estimates for certain nuclear power plants. There were no updates to decommissioning cost estimates for 2010.

In the first quarter of 2011, System Energy recorded a revision to its estimated decommissioning cost liability for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $38.9 million reduction in its decommissioning liability, along with a corresponding reduction in the related regulatory asset.

In the fourth quarter of 2011, Entergy Wholesale Commodities recorded a reduction of $34.1 million in the decommissioning cost liability for a plant as a result of a revised decommissioning cost study obtained to comply with a state regulatory requirement. The revised cost study resulted in a change in the undiscounted cash flows and a credit to decommissioning expense of $34.1 million ($21 million net-of-tax) was recorded, reflecting the excess of the reduction in the liability over the amount of undepreciated assets.

For the Indian Point 3 and FitzPatrick plants purchased in 2000, NYPA retained the decommissioning trusts and the decommissioning liability. NYPA and Entergy subsidiaries executed decommissioning agreements, which specify their decommissioning obligations. NYPA has the right to require the Entergy subsidiaries to assume the decommissioning liability provided that it assigns the corresponding decommissioning trust, up to a specified level, to the Entergy subsidiaries. If the decommissioning liability is retained by NYPA, the Entergy subsidiaries will perform the decommissioning of the plants at a price equal to the lesser of a pre-specified level or the amount in the decommissioning trusts. Entergy recorded an asset, which is now $521.6 million as of December 31, 2011, representing its estimate of the present value of the difference between the stipulated contract amount for decommissioning the plants less the decommissioning cost estimated in an independent decommissioning cost study. The asset is increased by monthly accretion based on the applicable discount rate necessary to ultimately provide for the estimated future value of the decommissioning contract. The monthly accretion is recorded as interest income.

Entergy maintains decommissioning trust funds that are committed to meeting the costs of decommissioning the nuclear power plants. The fair values of the decommissioning trust funds and the related asset retirement obligation regulatory assets of Entergy as of December 31, 2011 are as follows:

	Decommissioning Trust Fair Values	Regulatory Asset
	(In Millions)

Utility:
ANO 1 and ANO 2	$541.7	$181.5
River Bend	$420.9	$5.5
Waterford 3	$254.0	$116.1
Grand Gulf	$423.4	$59.6
Entergy Wholesale Commodities	$2,148.0	$-

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The fair values of the decommissioning trust funds and the related asset retirement obligation regulatory assets of Entergy as of December 31, 2010 are as follows:

	Decommissioning Trust Fair Values	Regulatory Asset
	(In Millions)

Utility:
ANO 1 and ANO 2	$520.8	$161.4
River Bend	$393.6	$10.9
Waterford 3	$240.5	$104.2
Grand Gulf	$387.9	$98.3
Entergy Wholesale Commodities	$2,052.9	$-

NOTE 10. LEASES (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

General

As of December 31, 2011, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities (excluding nuclear fuel leases and the Grand Gulf and Waterford 3 sale and leaseback transactions) with minimum lease payments as follows:

Year	Operating Leases	Capital Leases
	(In Thousands)

2012	$84,860	$6,494
2013	78,552	6,494
2014	78,559	4,694
2015	62,043	4,615
2016	37,963	4,457
Years thereafter	166,445	38,025
Minimum lease payments	508,422	64,779
Less: Amount representing interest	-	23,621
Present value of net minimum lease payments	$508,422	$41,158

Total rental expenses for all leases (excluding nuclear fuel leases and the Grand Gulf and Waterford 3 sale and leaseback transactions) amounted to $75.3 million in 2011, $80.8 million in 2010, and $71.6 million in 2009.

As of December 31, 2011, the Registrant Subsidiaries had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities (excluding nuclear fuel leases and the sale and leaseback transactions) with minimum lease payments as follows:

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Capital Leases

Year	Entergy Arkansas	Entergy Mississippi
	(In Thousands)

2012	$237	$3,370
2013	237	3,370
2014	237	1,570
2015	158	1,570
2016	-	1,570
Years thereafter	-	1,701
Minimum lease payments	869	13,151
Less: Amount representing interest	530	2,430
Present value of net minimum lease payments	$339	$10,721

Operating Leases

Year	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)

2012	$22,843	$11,437	$9,068	$6,192	$1,698	$5,646
2013	21,318	10,904	7,876	5,568	1,464	5,435
2014	20,296	17,596	6,522	4,466	1,320	4,028
2015	21,692	8,341	5,540	3,324	1,077	1,999
2016	7,545	7,901	2,171	1,878	728	1,066
Years thereafter	5,013	65,565	1,801	6,156	604	1,274
Minimum lease payments	$98,707	$121,744	$32,978	$27,584	$6,891	$19,448

Rental Expenses

Year	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Millions)

2011	$13.4	$12.2	$12.2	$5.2	$1.7	$8.4	$1.6
2010	$13.0	$12.5	$11.7	$5.5	$1.7	$7.4	$1.4
2009	$12.0	$11.6	$10.7	$5.3	$1.6	$9.9	$1.3

In addition to the above rental expense, railcar operating lease payments and oil tank facilities lease payments are recorded in fuel expense in accordance with regulatory treatment. Railcar operating lease payments were $8.3 million in 2011, $8.4 million in 2010, and $7.2 million in 2009 for Entergy Arkansas and $2.0 million in 2011, $2.3 million in 2010, and $3.1 million in 2009 for Entergy Gulf States Louisiana. Oil tank facilities lease payments for Entergy Mississippi were $3.4 million in 2011, $3.4 million in 2010, and $3.4 million in 2009.

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Sale and Leaseback Transactions

Waterford 3 Lease Obligations

In 1989, in three separate but substantially identical transactions, Entergy Louisiana sold and leased back undivided interests in Waterford 3 for the aggregate sum of $353.6 million. The interests represent approximately 9.3% of Waterford 3. The leases expire in 2017. Under certain circumstances, Entergy Louisiana may repurchase the leased interests prior to the end of the term of the leases. At the end of the lease terms, Entergy Louisiana has the option to repurchase the leased interests in Waterford 3 at fair market value or to renew the leases for either fair market value or, under certain conditions, a fixed rate.

Entergy Louisiana issued $208.2 million of non-interest bearing first mortgage bonds as collateral for the equity portion of certain amounts payable under the leases.

Upon the occurrence of certain events, Entergy Louisiana may be obligated to assume the outstanding bonds used to finance the purchase of the interests in the unit and to pay an amount sufficient to withdraw from the lease transaction. Such events include lease events of default, events of loss, deemed loss events, or certain adverse “Financial Events.” “Financial Events” include, among other things, failure by Entergy Louisiana, following the expiration of any applicable grace or cure period, to maintain (i) total equity capital (including preferred membership interests) at least equal to 30% of adjusted capitalization, or (ii) a fixed charge coverage ratio of at least 1.50 computed on a rolling 12 month basis. As of December 31, 2011, Entergy Louisiana was in compliance with these provisions.

As of December 31, 2011, Entergy Louisiana had future minimum lease payments (reflecting an overall implicit rate of 7.45%) in connection with the Waterford 3 sale and leaseback transactions, which are recorded as long-term debt, as follows:

		Amount
		(In Thousands)

2012		$39,067
2013		26,301
2014		31,036
2015		28,827
2016		16,938
Years thereafter		106,335
Total		248,504
Less: Amount representing interest		60,249
Present value of net minimum lease payments		$188,255

Grand Gulf Lease Obligations

In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million. The interests represent approximately 11.5% of Grand Gulf. The leases expire in 2015. Under certain circumstances, System Entergy may repurchase the leased interests prior to the end of the term of the leases. At the end of the lease terms, System Energy has the option to repurchase the leased interests in Grand Gulf at fair market value or to renew the leases for either fair market value or, under certain conditions, a fixed rate.

System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. For financial reporting purposes, System Energy expenses the interest portion of the lease obligation and the plant depreciation. However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes. Consistent with a recommendation contained in a

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FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term. The amount was a net regulatory asset (liability) of ($2.0) million and $60.6 million as of December 31, 2011 and 2010, respectively.

As of December 31, 2011, System Energy had future minimum lease payments (reflecting an implicit rate of 5.13%), which are recorded as long-term debt as follows:

		Amount
		(In Thousands)

2012		$49,959
2013		50,546
2014		51,637
2015		52,253
2016		-
Years thereafter		-
Total		204,395
Less: Amount representing interest		25,611
Present value of net minimum lease payments		$178,784

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NOTE 11. RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Qualified Pension Plans

Entergy has seven qualified pension plans covering substantially all employees: “Entergy Corporation Retirement Plan for Non-Bargaining Employees,” “Entergy Corporation Retirement Plan for Bargaining Employees,” “Entergy Corporation Retirement Plan II for Non-Bargaining Employees,” “Entergy Corporation Retirement Plan II for Bargaining Employees,” “Entergy Corporation Retirement Plan III,” “Entergy Corporation Retirement Plan IV for Non-Bargaining Employees,” and “Entergy Corporation Retirement Plan IV for Bargaining Employees.” The Registrant Subsidiaries participate in two of these plans: “Entergy Corporation Retirement Plan for Non-Bargaining Employees” and “Entergy Corporation Retirement Plan for Bargaining Employees.” Except for the Entergy Corporation Retirement Plan III, the pension plans are noncontributory and provide pension benefits that are based on employees’ credited service and compensation during the final years before retirement. The Entergy Corporation Retirement Plan III includes a mandatory employee contribution of 3% of earnings during the first 10 years of plan participation, and allows voluntary contributions from 1% to 10% of earnings for a limited group of employees.

The assets of the seven qualified pension plans are held in a master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts of the master trust that is maintained by a trustee. Use of the master trust permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets are commingled in the master trust, the trustee maintains supporting records for the purpose of allocating the equity in net earnings (loss) and the administrative expenses of the investment accounts to the various participating pension plans. The fair value of the trust assets is determined by the trustee and certain investment managers. The trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trust on a pro rata basis.

Further, within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment income and contributions, and decreased for benefit payments. A plan’s investment net income/(loss) (i.e. interest and dividends, realized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter.

Entergy Corporation and its subsidiaries fund pension costs in accordance with contribution guidelines established by the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions.

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Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI)

Entergy Corporation and its subsidiaries’ total 2011, 2010, and 2009 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components:

	2011	2010	2009
	(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period	$121,961	$104,956	$89,646
Interest cost on projected benefit obligation	236,992	231,206	218,172
Expected return on assets	(301,276)	(259,608)	(249,220)
Amortization of prior service cost	3,350	4,658	4,997
Recognized net loss	92,977	65,901	22,401
Net periodic pension costs	$154,004	$147,113	$85,996

Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net loss	$1,045,624	$232,279	$76,799
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of prior service cost	(3,350)	(4,658)	(4,997)
Amortization of net loss	(92,977)	(65,901)	(22,401)
Total	949,297	161,720	49,401

Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)	$1,103,301	$308,834	$135,397

Estimated amortization amounts from regulatory asset and/or AOCI to net periodic cost in the following year
Prior service cost	$2,733	$3,350	$4,658
Net loss	$169,064	$92,977	$65,901

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Notes to Financial Statements

The Registrant Subsidiaries’ total 2011, 2010, and 2009 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the following components:

2011	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period	$18,072	$9,848	$11,543	$5,308	$2,242	$4,788	$4,941
Interest cost on projected benefit obligation	51,965	23,713	32,636	15,637	7,050	15,971	11,758
Expected return on assets	(62,434)	(33,358)	(38,866)	(20,152)	(8,455)	(22,005)	(15,138)
Amortization of prior service cost	459	79	280	152	35	65	16
Recognized net loss	25,681	9,118	17,990	6,717	4,666	5,579	5,284
Net pension cost	$33,743	$9,400	$23,583	$7,662	$5,538	$4,398	$6,861

Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net loss	$217,989	$102,329	$137,100	$56,714	$29,297	$64,662	$52,876
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of prior service cost	(459)	(79)	(280)	(152)	(35)	(65)	(16)
Amortization of net loss	(25,681)	(9,118)	(17,990)	(6,717)	(4,666)	(5,579)	(5,284)
Total	$191,849	$93,132	$118,830	$49,845	$24,596	$59,018	$47,576

Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)	$225,592	$102,532	$142,413	$57,507	$30,134	$63,416	$54,437

Estimated amortization amounts from regulatory asset and/or AOCI to net periodic cost in the following year
Prior service cost	$200	$19	$208	$30	$7	$15	$13
Net loss	$41,309	$16,295	$28,486	$10,667	$6,935	$10,261	$9,135

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Notes to Financial Statements

2010	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period	$15,775	$8,462	$9,770	$4,651	$2,063	$4,267	$4,132
Interest cost on projected benefit obligation	49,277	24,377	28,541	15,230	6,040	15,869	9,009
Expected return on assets	(50,635)	(30,752)	(32,775)	(17,252)	(7,236)	(20,549)	(11,808)
Amortization of prior service cost	782	302	474	318	177	237	34
Recognized net loss	16,506	7,622	8,604	4,361	2,544	3,208	523
Net pension cost	$31,705	$10,011	$14,614	$7,308	$3,588	$3,032	$1,890

Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net loss	$97,117	$4,748	$99,129	$21,801	$22,600	$17,316	$56,756
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of prior service cost	(782)	(302)	(474)	(318)	(177)	(237)	(34)
Amortization of net loss	(16,506)	(7,622)	(8,604)	(4,361)	(2,544)	(3,208)	(523)
Total	$79,829	($3,176)	$90,051	$17,122	$19,879	$13,871	$56,199

Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)	$111,534	$6,835	$104,665	$24,430	$23,467	$16,903	$58,089

Estimated amortization amounts from regulatory asset and/or AOCI to net periodic cost in the following year
Prior service cost	$459	$79	$280	$152	$35	$65	$16
Net loss	$25,681	$9,118	$17,990	$6,717	$4,666	$5,579	$5,284

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Notes to Financial Statements

2009	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period	$13,601	$6,993	$7,896	$3,981	$1,701	$3,668	$3,519
Interest cost on projected benefit obligation	47,043	21,116	27,760	14,706	5,878	15,741	8,555
Expected return on assets	(48,749)	(30,065)	(32,789)	(16,943)	(7,261)	(20,740)	(11,064)
Amortization of prior service cost	849	438	474	341	206	321	34
Recognized net loss	7,058	319	2,817	1,289	1,225	168	439
Net pension cost/(income)	$19,802	($1,199)	$6,158	$3,374	$1,749	($842)	$1,483

Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net loss/(gain)	$32,528	$36,704	$7,113	$5,609	$724	($3,444)	$5,076
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of prior service cost	(849)	(438)	(474)	(341)	(206)	(321)	(34)
Amortization of net loss	(7,058)	(319)	(2,817)	(1,289)	(1,225)	(168)	(439)
Total	$24,621	$35,947	$3,822	$3,979	($707)	($3,933)	$4,603

Total recognized as net periodic pension cost/(income), regulatory asset, and/or AOCI (before tax)	$44,423	$34,748	$9,980	$7,353	$1,042	($4,775)	$6,086

Estimated amortization amounts from regulatory asset and/or AOCI to net periodic cost in the following year
Prior service cost	$782	$302	$474	$318	$177	$237	$34
Net loss	$16,506	$7,621	$8,603	$4,362	$2,544	$3,207	$523

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Notes to Financial Statements

Qualified Pension Obligations, Plan Assets, Funded Status, Amounts Recognized in the Balance Sheet for Entergy Corporation and its Subsidiaries as of December 31, 2011 and 2010

	December 31,
	2011	2010
	(In Thousands)
Change in Projected Benefit Obligation (PBO)
Balance at beginning of year	$4,301,218	$3,837,744
Service cost	121,961	104,956
Interest cost	236,992	231,206
Actuarial loss	703,895	293,189
Employee contributions	828	894
Benefits paid	(177,259)	(166,771)
Balance at end of year	$5,187,635	$4,301,218

Change in Plan Assets
Fair value of assets at beginning of year	$3,216,268	$2,607,274
Actual return on plan assets	(40,453)	320,517
Employer contributions	400,532	454,354
Employee contributions	828	894
Benefits paid	(177,259)	(166,771)
Fair value of assets at end of year	$3,399,916	$3,216,268

Funded status	($1,787,719)	($1,084,950)

Amount recognized in the balance sheet
Non-current liabilities	($1,787,719)	($1,084,950)

Amount recognized as a regulatory asset
Prior service cost	$9,836	$12,979
Net loss	2,048,743	1,350,616
	$2,058,579	$1,363,595
Amount recognized as AOCI (before tax)
Prior service cost	$2,648	$2,855
Net loss	551,613	297,093
	$554,261	$299,948

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Notes to Financial Statements

Qualified Pension Obligations, Plan Assets, Funded Status, and Amounts Recognized in the Balance Sheet for the Registrant Subsidiaries as of December 31, 2011 and 2010

2011	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Change in Projected Benefit
Obligation (PBO)
Balance at beginning of year	$950,595	$431,870	$596,730	$286,179	$128,477	$292,551	$213,098
Service cost	18,072	9,848	11,543	5,308	2,242	4,788	4,941
Interest cost	51,965	23,713	32,636	15,637	7,050	15,971	11,758
Actuarial loss	146,514	65,000	93,175	33,865	19,695	40,122	35,775
Benefits paid	(50,574)	(17,999)	(29,336)	(14,612)	(5,498)	(15,763)	(7,304)
Balance at end of year	$1,116,572	$512,432	$704,748	$326,377	$151,966	$337,669	$258,268

Change in Plan Assets
Fair value of assets at beginning of year	$646,491	$361,207	$406,216	$212,122	$88,688	$237,502	$128,007
Actual return on plan assets	(9,042)	(3,971)	(5,059)	(2,698)	(1,148)	(2,536)	(1,963)
Employer contributions	120,400	27,318	60,597	29,169	12,160	18,235	28,351
Benefits paid	(50,574)	(17,999)	(29,336)	(14,612)	(5,498)	(15,763)	(7,304)
Fair value of assets at end of year	$707,275	$366,555	$432,418	$223,981	$94,202	$237,439	$147,091

Funded status	($409,297)	($145,877)	($272,330)	($102,396)	($57,764)	($100,231)	($111,177)

Amounts recognized in the balance sheet (funded status)
Non-current liabilities	($409,297)	($145,877)	($272,330)	($102,396)	($57,764)	($100,231)	($111,177)

Amounts recognized as regulatory asset
Prior service cost	$223	$23	$291	$39	$10	$22	$19
Net loss	619,430	214,833	408,835	169,329	95,667	171,023	165,011
	$619,653	$214,856	$409,126	$169,368	$95,677	$171,045	$165,030

Amounts recognized as AOCI (before tax)
Prior service cost	$-	$6	$-	$-	$-	$-	$-
Net loss	-	50,393	-	-	-	-	-
	$-	$50,399	$-	$-	$-	$-	$-

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Notes to Financial Statements

2010	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Change in Projected Benefit
Obligation (PBO)
Balance at beginning of year	$824,261	$405,228	$480,503	$255,057	$101,325	$266,371	$149,387
Service cost	15,775	8,462	9,770	4,651	2,063	4,267	4,132
Interest cost	49,277	24,377	28,541	15,230	6,040	15,869	9,009
Actuarial loss	108,171	11,050	106,227	25,438	24,211	21,055	56,841
Employee contribution	-	-	-	-	-	-	2
Benefits paid	(46,889)	(17,247)	(28,311)	(14,197)	(5,162)	(15,011)	(6,273)
Balance at end of year	$950,595	$431,870	$596,730	$286,179	$128,477	$292,551	$213,098

Change in Plan Assets
Fair value of assets at beginning of year	$494,732	$310,445	$328,520	$171,912	$72,046	$209,936	$91,061
Actual return on plan assets	61,690	37,054	39,872	20,889	8,847	24,289	11,893
Employer contributions	136,958	30,955	66,135	33,518	12,957	18,288	31,324
Employee contribution	-	-	-	-	-	-	2
Benefits paid	(46,889)	(17,247)	(28,311)	(14,197)	(5,162)	(15,011)	(6,273)
Fair value of assets at end of year	$646,491	$361,207	$406,216	$212,122	$88,688	$237,502	$128,007

Funded status	($304,104)	($70,663)	($190,514)	($74,057)	($39,789)	($55,049)	($85,091)

Amounts recognized in the balance sheet (funded status)
Non-current liabilities	($304,104)	($70,663)	($190,514)	($74,057)	($39,789)	($55,049)	($85,091)

Amounts recognized as regulatory asset
Prior service cost	$682	$88	$571	$191	$45	$86	$35
Net loss	427,122	141,052	289,726	119,333	71,035	111,940	117,419
	$427,804	$141,140	$290,297	$119,524	$71,080	$112,026	$117,454

Amounts recognized as AOCI (before tax)
Prior service cost	$-	$19	$-	$-	$-	$-	$-
Net loss	-	30,963	-	-	-	-	-
	$-	$30,982	$-	$-	$-	$-	$-

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Notes to Financial Statements

Other Postretirement Trusts

2011	Level 1		Level 2		Level 3	Total
	(In Thousands)
Equity securities:
Common collective trust	$-		$208,812	(c)	$-	$208,812
Fixed income securities:
U.S. Government securities	42,577	(b)	57,151	(a)	-	99,728
Corporate debt instruments	-		42,807	(a)	-	42,807
Registered investment companies	4,659	(d)	-		-	4,659
Other	-		69,287	(f)	-	69,287
Total investments	$47,236		$378,057		$-	$425,293

Other pending transactions						(235)
Plus: Other postretirement assets included in the investments of the qualified pension trust						2,114
Total fair value of other postretirement assets						$427,172

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Notes to Financial Statements

2010	Level 1		Level 2		Level 3	Total
	(In Thousands)
Equity securities:
Common collective trust	$-		$211,835	(c)	$-	$211,835
Fixed income securities:
Interest-bearing cash	4,014	(d)	-		-	4,014
U.S. Government securities	37,823	(b)	52,326	(a)	-	90,149
Corporate debt instruments	-		37,128	(a)	-	37,128
Other	-		58,716	(f)	-	58,716
Total investments	$41,837		$360,005		$-	$401,842

Other pending transactions						193
Plus: Other postretirement assets included in the investments of the qualified pension trust						2,395
Total fair value of other postretirement assets						$404,430

(a)	Certain preferred stocks and fixed income debt securities (corporate, government, and securitized) are stated at fair value as determined by broker quotes.
(b)	Common stocks, treasury notes and bonds, and certain preferred stocks and fixed income debt securities are stated at fair value determined by quoted market prices.
(c)	The common collective trusts hold investments in accordance with stated objectives. The investment strategy of the trusts is to capture the growth potential of equity markets by replicating the performance of a specified index. Net asset value per share of the common collective trusts estimate fair value.
(d)	The registered investment company is a money market mutual fund with a stable net asset value of one dollar per share.
(e)	The registered investment company holds investments in domestic and international bond markets and estimates fair value using net asset value per share.
(f)	The other remaining assets are U.S. municipal and foreign government bonds stated at fair value as determined by broker quotes
(g)	The unallocated insurance contract investments are recorded at contract value, which approximates fair value. The contract value represents contributions made under the contract, plus interest, less funds used to pay benefits and contract expenses, and less distributions to the master trust.

Accumulated Pension Benefit Obligation

The accumulated benefit obligation for Entergy’s qualified pension plans was $4.6 billion and $3.8 billion at December 31, 2011 and 2010, respectively.

The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries as of December 31, 2011 and 2010 was as follows:

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Notes to Financial Statements

	December 31,
	2011	2010
	(In Thousands)

Entergy Arkansas	$1,013,605	$864,476
Entergy Gulf States Louisiana	$459,037	$388,292
Entergy Louisiana	$632,759	$537,329
Entergy Mississippi	$296,259	$261,248
Entergy New Orleans	$136,390	$115,223
Entergy Texas	$308,628	$268,350
System Energy	$227,617	$185,904

Estimated Future Benefit Payments

Based upon the assumptions used to measure Entergy’s qualified pension and other postretirement benefit obligations at December 31, 2011, and including pension and other postretirement benefits attributable to estimated future employee service, Entergy expects that benefits to be paid and the Medicare Part D subsidies to be received over the next ten years for Entergy Corporation and its subsidiaries will be as follows:

	Estimated Future Benefits Payments
	Qualified Pension	Non-Qualified Pension	Other Postretirement (before Medicare Subsidy)	Estimated Future Medicare Subsidy Receipts
	(In Thousands)
Year(s)
2012	$178,030	$11,199	$72,685	$5,678
2013	$189,881	$18,159	$76,731	$6,374
2014	$204,573	$14,942	$81,001	$7,137
2015	$220,295	$15,502	$85,780	$7,935
2016	$238,242	$22,492	$90,143	$8,828
2017 - 2021	$1,524,241	$72,724	$523,040	$59,306

Based upon the same assumptions, Entergy expects that benefits to be paid and the Medicare Part D subsidies to be received over the next ten years for the Registrant Subsidiaries will be as follows:

Estimated Future Qualified Pension Benefits Payments	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Year(s)
2012	$49,373	$17,845	$29,047	$14,367	$5,569	$15,596	$7,280
2013	$50,592	$18,860	$30,151	$15,145	$5,879	$16,313	$7,760
2014	$52,263	$20,136	$31,471	$16,160	$6,208	$17,007	$8,439
2015	$54,616	$21,662	$32,890	$17,120	$6,648	$17,818	$9,096
2016	$57,215	$23,372	$34,430	$18,093	$7,141	$18,702	$9,949
2017 - 2021	$338,476	$148,495	$203,838	$105,637	$45,010	$108,504	$67,858

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Notes to Financial Statements

Estimated Future Non-Qualified Pension Benefits Payments	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Year(s)
2012	$272	$260	$18	$114	$25	$1,029
2013	$237	$252	$17	$172	$24	$1,004
2014	$405	$260	$15	$137	$23	$2,063
2015	$378	$241	$14	$132	$22	$757
2016	$334	$234	$13	$125	$22	$796
2017 - 2021	$1,993	$1,078	$44	$767	$158	$3,267

Estimated Future Other Postretirement Benefits Payments (before Medicare Part D Subsidy)	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Year(s)
2012	$15,836	$8,288	$9,953	$4,708	$4,885	$7,060	$2,390
2013	$16,388	$8,871	$10,289	$4,953	$4,944	$7,311	$2,478
2014	$16,850	$9,360	$10,747	$5,261	$5,025	$7,602	$2,627
2015	$17,536	$10,023	$11,173	$5,590	$5,116	$7,932	$2,813
2016	$18,096	$10,572	$11,628	$5,875	$5,181	$8,282	$2,934
2017 - 2021	$98,651	$61,346	$64,660	$33,394	$26,449	$46,702	$17,398

Estimated Future Medicare Part D Subsidy	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Year(s)
2012	$1,374	$637	$810	$509	$472	$624	$108
2013	$1,516	$700	$895	$558	$498	$684	$141
2014	$1,686	$778	$975	$608	$519	$741	$172
2015	$1,841	$847	$1,066	$655	$535	$796	$205
2016	$2,017	$930	$1,155	$710	$552	$848	$246
2017 - 2021	$13,058	$6,049	$7,304	$4,428	$2,955	$4,970	$1,927

Contributions

Entergy currently expects to contribute approximately $163 million to its qualified pension plans and approximately $80.4 million to other postretirement plans in 2012. The expected 2012 pension and other postretirement plan contributions of the Registrant Subsidiaries are shown below. The required pension contributions will not be known with more certainty until the January 1, 2012 valuations are completed by April 1, 2012, however Entergy’s preliminary estimates of 2012 funding requirements indicate that the contributions will not exceed historical levels of pension contributions.

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Notes to Financial Statements

The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans in 2012:

	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)

Pension Contributions	$31,855	$10,765	$23,774	$8,400	$4,817	$7,653	$8,855
Other Postretirement Contributions	$26,675	$8,288	$9,953	$5,469	$3,669	$5,153	$4,090

Actuarial Assumptions

The significant actuarial assumptions used in determining the pension PBO and the other postretirement benefit APBO as of December 31, 2011, and 2010 were as follows:

	2011	2010

Weighted-average discount rate:
Qualified pension	5.10% - 5.20%	5.60% - 5.70%
Other postretirement	5.10%	5.50%
Non-qualified pension	4.40%	4.90%
Weighted-average rate of increase in future compensation levels	4.23%	4.23%

The significant actuarial assumptions used in determining the net periodic pension and other postretirement benefit costs for 2011, 2010, and 2009 were as follows:

	2011	2010	2009

Weighted-average discount rate:
Qualified pension	5.60% - 5.70%	6.10% - 6.30%	6.75%
Other postretirement	5.50%	6.10%	6.70%
Non-qualified pension	4.90%	5.40%	6.75%
Weighted-average rate of increase in future compensation levels	4.23%	4.23%	4.23%
Expected long-term rate of return on plan assets:
Pension assets	8.50%	8.50%	8.50%
Other postretirement non-taxable assets	7.75%	7.75%	8.50%
Other postretirement taxable assets	5.50%	5.50%	6.00%

Entergy’s other postretirement benefit transition obligations are being amortized over 20 years ending in 2012.

The assumed health care cost trend rate used in measuring Entergy’s December 31, 2011 APBO was 7.75% for pre-65 retirees and 7.5% for post-65 retirees for 2012, gradually decreasing each successive year until it reaches 4.75% in 2022 and beyond for both pre-65 and post-65 retirees. The assumed health care cost trend rate used in measuring Entergy’s 2011 Net Other Postretirement Benefit Cost was 8.5% for pre-65 retirees and 8.0% for post-65 retirees for 2011, gradually decreasing each successive year until it reaches 4.75% in 2019 and beyond for pre-65 retirees and 4.75% in 2018 and beyond for post-65 retirees. A one percentage point change in the assumed health care cost trend rate for 2011 would have the following effects:

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Notes to Financial Statements

	1 Percentage Point Increase		1 Percentage Point Decrease
2011	Impact on the APBO	Impact on the sum of service costs and interest cost	Impact on the APBO	Impact on the sum of service costs and interest cost
	Increase /(Decrease) (In Thousands)

Entergy Corporation and its subsidiaries	$218,138	$23,318	($183,492)	($18,721)

A one percentage point change in the assumed health care cost trend rate for 2011 would have the following effects for the Registrant Subsidiaries:

	1 Percentage Point Increase		1 Percentage Point Decrease
2011	Impact on the APBO	Impact on the sum of service costs and interest cost	Impact on the APBO	Impact on the sum of service costs and interest cost
	Increase/(Decrease) (In Thousands)

Entergy Arkansas	$34,824	$3,427	($28,552)	($2,723)
Entergy Gulf States Louisiana	$26,263	$2,576	($21,412)	($2,034)
Entergy Louisiana	$23,274	$2,558	($20,827)	($2,097)
Entergy Mississippi	$11,603	$1,113	($9,529)	($884)
Entergy New Orleans	$6,509	$628	($6,229)	($541)
Entergy Texas	$16,598	$1,454	($13,689)	($1,159)
System Energy	$9,029	$999	($7,294)	($785)

Medicare Prescription Drug, Improvement and Modernization Act of 2003

In December 2003, the Medicare Prescription Drug, Improvement and Modernization Act of 2003 became law. The Act introduces a prescription drug benefit cost under Medicare (Part D), which started in 2006, as well as a federal subsidy to employers who provide a retiree prescription drug benefit that is at least actuarially equivalent to Medicare Part D.

The actuarially estimated effect of future Medicare subsidies reduced the December 31, 2011 and 2010 Accumulated Postretirement Benefit Obligation by $274 million and $267 million, respectively, and reduced the 2011, 2010, and 2009 other postretirement benefit cost by $33.0 million, $26.6 million, and $24.0 million, respectively. In 2011, Entergy received $4.6 million in Medicare subsidies for prescription drug claims.

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The actuarially estimated effect of future Medicare subsidies and the actual subsidies received for the Registrant Subsidiaries was as follows:

	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	Increase/(Decrease) In Thousands
Impact on 12/31/2011 APBO	($55,684)	($27,834)	($31,693)	($17,687)	($10,500)	($19,346)	($11,036)
Impact on 12/31/2010 APBO	($55,459)	($27,330)	($31,259)	($17,998)	($11,073)	($19,830)	($10,431)

Impact on 2011 other postretirement benefit cost	($6,309)	($3,923)	($3,889)	($2,016)	($1,170)	($1,528)	($1,403)
Impact on 2010 other postretirement benefit cost	($5,254)	($3,401)	($3,143)	($1,649)	($1,070)	($1,109)	($1,068)

Medicare subsidies received in 2011	$1,025	$585	$683	$336	$358	$489	$116

Defined Contribution Plans

Entergy sponsors the Savings Plan of Entergy Corporation and Subsidiaries (System Savings Plan). The System Savings Plan is a defined contribution plan covering eligible employees of Entergy and its subsidiaries. The employing Entergy subsidiary makes matching contributions for all non-bargaining and certain bargaining employees to the System Savings Plan in an amount equal to 70% of the participants’ basic contributions, up to 6% of their eligible earnings per pay period. The 70% match is allocated to investments as directed by the employee.

Entergy also sponsors the Savings Plan of Entergy Corporation and Subsidiaries IV (established in 2002), the Savings Plan of Entergy Corporation and Subsidiaries VI (established in April 2007), and the Savings Plan of Entergy Corporation and Subsidiaries VII (established in April 2007) to which matching contributions are also made. The plans are defined contribution plans that cover eligible employees, as defined by each plan, of Entergy and its subsidiaries. Effective June 3, 2010, employees participating in the Savings Plan of Entergy Corporation and Subsidiaries II (Savings Plan II) were transferred into the System Savings Plan when Savings Plan II merged into the System Savings Plan.

Entergy’s subsidiaries’ contributions to defined contribution plans collectively were $42.6 million in 2011, $41.8 million in 2010, and $41.9 million in 2009. The majority of the contributions were to the System Savings Plan.

The Registrant Subsidiaries’ 2011, 2010, and 2009 contributions to defined contribution plans were as follows:

Year	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)

2011	$3,183	$1,804	$2,260	$1,894	$725	$1,613
2010	$3,177	$1,792	$2,289	$1,886	$683	$1,626
2009	$3,197	$1,828	$2,356	$1,906	$732	$1,712

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NOTE 12. STOCK-BASED COMPENSATION (Entergy Corporation)

Entergy grants stock options and long-term incentive and restricted liability awards to key employees of the Entergy subsidiaries under its Equity Ownership Plans which are shareholder-approved stock-based compensation plans. The Equity Ownership Plan, as restated in February 2003 (2003 Plan), had 722,251 authorized shares remaining for long-term incentive and restricted liability awards as of December 31, 2011. Effective January 1, 2007, Entergy’s shareholders approved the 2007 Equity Ownership and Long-Term Cash Incentive Plan (2007 Plan). The maximum aggregate number of common shares that can be issued from the 2007 Plan for stock-based awards is 7,000,000 with no more than 2,000,000 available for non-option grants. The 2007 Plan, which only applies to awards made on or after January 1, 2007, will expire after 10 years. As of December 31, 2011, there were 1,052,035 authorized shares remaining for stock-based awards, all of which are available for non-option grants. Effective May 6, 2011, Entergy’s shareholders approved the 2011 Equity Ownership and Long-Term Cash Incentive Plan (2011 Plan). The maximum number of common shares that can be issued from the 2011 Plan for stock-based awards is 5,500,000 with no more than 2,000,000 available for incentive stock option grants. The 2011 Plan, which only applies to awards made on or after May 6, 2011, will expire after 10 years. As of December 31, 2011, there were 5,495,276 authorized shares remaining for stock-based awards, including 2,000,000 for incentive stock option grants.

Stock Options

Stock options are granted at exercise prices that equal the closing market price of Entergy Corporation common stock on the date of grant. Generally, stock options granted will become exercisable in equal amounts on each of the first three anniversaries of the date of grant. Unless they are forfeited previously under the terms of the grant, options expire ten years after the date of the grant if they are not exercised.

The following table includes financial information for stock options for each of the years presented:

	2011	2010	2009
	(In Millions)

Compensation expense included in Entergy’s Consolidated Net Income	$10.4	$15.0	$16.8
Tax benefit recognized in Entergy’s Consolidated Net Income	$4.0	$5.8	$6.5
Compensation cost capitalized as part of fixed assets and inventory	$2.0	$2.9	$3.2

Entergy determines the fair value of the stock option grants by considering factors such as lack of marketability, stock retention requirements, and regulatory restrictions on exercisability in accordance with accounting standards. The stock option weighted-average assumptions used in determining the fair values are as follows:

	2011	2010	2009

Stock price volatility	24.25%	25.73%	24.39%
Expected term in years	6.64	5.46	5.33
Risk-free interest rate	2.70%	2.57%	2.22%
Dividend yield	4.20%	3.74%	3.50%
Dividend payment per share	$3.32	$3.24	$3.00

Stock price volatility is calculated based upon the weekly public stock price volatility of Entergy Corporation common stock over the last four to five years. The expected term of the options is based upon historical option exercises and the weighted average life of options when exercised and the estimated weighted average life of all vested but unexercised options. In 2008, Entergy implemented stock ownership guidelines for its senior executive officers. These

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guidelines require an executive officer to own shares of Entergy common stock equal to a specified multiple of his or her salary. Until an executive officer achieves this ownership position the executive officer is required to retain 75% of the after-tax net profit upon exercise of the option to be held in Entergy Corporation common stock. The reduction in fair value of the stock options due to this restriction is based upon an estimate of the call option value of the reinvested gain discounted to present value over the applicable reinvestment period.

A summary of stock option activity for the year ended December 31, 2011 and changes during the year are presented below:

	Number of Options	Weighted- Average Exercise Price	Aggregate Intrinsic Value	Weighted- Average Contractual Life

Options outstanding as of January 1, 2011	11,225,725	$72.45

Options granted	388,200	$72.79
Options exercised	(1,079,008)	$42.43
Options forfeited/expired	(75,499)	$86.62
Options outstanding as of December 31, 2011	10,459,418	$75.46	$-	4.7 years

Options exercisable as of December 31, 2011	9,011,257	$75.36	$-	4.1 years
Weighted-average grant-date fair value of options granted during 2011	$11.48

The weighted-average grant-date fair value of options granted during the year was $13.18 for 2010 and $12.47 for 2009. The total intrinsic value of stock options exercised was $29.6 million during 2011, $36.6 million during 2010, and $35.6 million during 2009. The intrinsic value, which has no effect on net income, of the stock options exercised is calculated by the difference in Entergy Corporation’s common stock price on the date of exercise and the exercise price of the stock options granted. Because Entergy’s year-end stock price is less than the weighted average exercise price, the aggregate intrinsic value of outstanding stock options as of December 31, 2011 was zero. The intrinsic value of “in the money” stock options is $67 million as of December 31, 2011. Entergy recognizes compensation cost over the vesting period of the options based on their grant-date fair value. The total fair value of options that vested was approximately $16 million during 2011, $21 million during 2010, and $22 million during 2009.

The following table summarizes information about stock options outstanding as of December 31, 2011:

	Options Outstanding			Options Exercisable
Range of Exercise Prices	As of 12/31/2011	Weighted-Avg. Remaining Contractual Life-Yrs.	Weighted- Avg. Exercise Price	Number Exercisable as of 12/31/2011	Weighted- Avg. Exercise Price

$37 - $50.99	1,468,761	0.6	$43.22	1,468,761	$43.22
$51 - $64.99	966,155	2.2	$58.58	966,155	$58.58
$65 - $78.99	4,911,618	5.8	$73.09	3,463,457	$71.86
$79 - $91.99	1,627,384	5.1	$91.82	1,627,384	$91.82
$92 - $108.20	1,485,500	6.1	$108.20	1,485,500	$108.20
$37 - $108.20	10,459,418	4.7	$75.46	9,011,257	$75.36

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Stock-based compensation cost related to non-vested stock options outstanding as of December 31, 2011 not yet recognized is approximately $10 million and is expected to be recognized on a weighted-average period of 1.3 years.

Restricted Stock Awards

In January 2011, the Board approved and Entergy granted 166,800 restricted stock awards under the 2007 Equity Ownership and Long-term Cash Incentive Plan. The grants were made effective as of January 27, 2011 and were valued at $72.79 per share, which was the closing price of Entergy’s common stock on that date. One-third of the restricted stock awards will vest upon each anniversary of the grant date and are expensed ratably over the three year vesting period. Shares of restricted stock have the same dividend and voting rights as other common stock and are considered issued and outstanding shares of Entergy upon vesting.

The following table includes financial information for restricted stock for each of the years presented:

	2011	2010	2009
	(In Millions)

Compensation expense included in Entergy’s Consolidated Net Income	$3.9	$-	$-
Tax benefit recognized in Entergy’s Consolidated Net Income	$1.5	$-	$-
Compensation cost capitalized as part of fixed assets and inventory	$0.7	$-	$-

Long-Term Incentive Awards

Entergy grants long-term incentive awards earned under its stock benefit plans in the form of performance units, which are equal to the cash value of shares of Entergy Corporation common stock at the end of the performance period, which is the last trading day of the year. Performance units will pay out to the extent that the performance conditions are satisfied. In addition to the potential for equivalent share appreciation or depreciation, performance units will earn the cash equivalent of the dividends paid during the three-year performance period applicable to each plan. The costs of incentive awards are charged to income over the three-year period.

The following table includes financial information for the long-term incentive awards for each of the years presented:

	2011	2010	2009
	(In Millions)

Fair value of long-term incentive awards as of December 31,	$7.3	$10.1	$17.2
Compensation expense included in Entergy’s Consolidated Net Income for the year	$0.7	($0.9)	$5.6
Tax benefit (expense) recognized in Entergy’s Consolidated Net Income for the year	$0.3	($0.4)	$2.2
Compensation cost capitalized as part of fixed assets and inventory	$0.1	$0.1	$1.0

Entergy paid $0.7 million in 2011 for awards earned under the Long-Term Incentive Plan. The distribution is applicable to the 2008 – 2010 performance period.

Restricted Unit Awards

Entergy grants restricted unit awards earned under its stock benefit plans in the form of stock units that are subject to time-based restrictions. The restricted units are equal to the cash value of shares of Entergy Corporation common stock at the time of vesting. The costs of restricted unit awards are charged to income over the restricted period, which varies from grant to grant. The average vesting period for restricted unit awards granted is 36 months. As of December 31, 2011, there were 138,965 unvested restricted units that are expected to vest over an average period of 10 months.

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The following table includes financial information for restricted unit awards for each of the years presented:

	2011	2010	2009
	(In Millions)

Fair value of restricted awards as of December 31,	$6.6	$8.3	$4.6
Compensation expense included in Entergy’s Consolidated Net Income for the year	$3.7	$3.9	$2.0
Tax benefit recognized in Entergy’s Consolidated Net Income for the year	$1.4	$1.5	$0.8
Compensation cost capitalized as part of fixed assets and inventory	$0.7	$0.9	$0.5

Entergy paid $5.9 million in 2011 for awards under the Restricted Units Awards Plan.

NOTE 13. BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy’s reportable segments as of December 31, 2011 are Utility and Entergy Wholesale Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale Commodities includes the ownership and operation of six nuclear power plants located in the northern United States and the sale of the electric power produced by those plants to wholesale customers. Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation, and other business activity, including the earnings on the proceeds of sales of previously-owned businesses.

Entergy’s segment financial information is as follows:

2011	Utility	Entergy Wholesale Commodities*	All Other	Eliminations	Consolidated
	(In Thousands)

Operating revenues	$8,841,827	$2,413,773	$4,157	($30,684)	$11,229,073
Deprec., amort. & decomm.	$1,027,597	$260,638	$4,562	$-	$1,292,797
Interest and investment income	$158,737	$136,492	$28,830	($194,925)	$129,134
Interest expense	$455,739	$20,634	$121,599	($84,345)	$513,627
Income taxes	$27,311	$225,456	$33,496	$-	$286,263
Consolidated net income (loss)	$1,123,866	$491,841	($137,755)	($110,580)	$1,367,372
Total assets	$32,734,549	$10,533,080	($507,860)	($2,058,070)	$40,701,699
Investment in affiliates - at equity	$199	$44,677	$-	$-	$44,876
Cash paid for long-lived asset additions	$2,351,913	$1,048,146	($402)	$-	$3,399,657

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2010	Utility	Entergy Wholesale Commodities*	All Other	Eliminations	Consolidated
	(In Thousands)

Operating revenues	$8,941,332	$2,566,156	$7,442	($27,353)	$11,487,577
Deprec., amort. & decomm.	$1,006,385	$270,658	$4,587	$-	$1,281,630
Interest and investment income	$182,493	$171,158	$44,757	($212,953)	$185,455
Interest expense	$493,241	$71,817	$129,505	($119,396)	$575,167
Income taxes (benefits)	$454,227	$268,649	($105,637)	$-	$617,239
Consolidated net income	$829,719	$489,422	$44,721	($93,557)	$1,270,305
Total assets	$31,080,240	$10,102,817	($714,968)	($1,782,813)	$38,685,276
Investment in affiliates - at equity	$199	$59,456	($18,958)	$-	$40,697
Cash paid for long-lived asset additions	$1,766,609	$687,313	$75	$-	$2,453,997

2009	Utility	Entergy Wholesale Commodities*	All Other	Eliminations	Consolidated
	(In Thousands)

Operating revenues	$8,055,353	$2,711,078	$5,682	($26,463)	$10,745,650
Deprec., amort. & decomm.	$1,025,922	$251,147	$4,769	$-	$1,281,838
Interest and investment income (loss)	$180,505	$196,492	($10,470)	($129,899)	$236,628
Interest expense	$462,206	$78,278	$86,420	($56,460)	$570,444
Income taxes (benefits)	$388,682	$322,255	($78,197)	$-	$632,740
Consolidated net income (loss)	$708,905	$641,094	($25,511)	($73,438)	$1,251,050
Total assets	$29,892,088	$11,134,791	($646,756)	($2,818,170)	$37,561,953
Investment in affiliates - at equity	$200	$-	$39,380	$-	$39,580
Cash paid for long-lived asset additions	$1,872,997	$661,596	($5,874)	$-	$2,528,719

Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.

On April 5, 2010, Entergy announced that, effective immediately, it planned to unwind the business infrastructure associated with its proposed plan to spin-off its non-utility nuclear business. As a result of the plan to unwind the business infrastructure, Entergy recorded expenses in the Entergy Wholesale Commodities segment. Other operating and maintenance expense includes the write-off of $64 million of capital costs, primarily for software that will not be utilized. Interest charges include the write-off of $39 million of debt financing costs, primarily incurred for the $1.2 billion credit facility related to the planned spin-off of Entergy’s non-utility nuclear business that will not be used. Approximately $16 million of other costs were incurred in 2010 in connection with unwinding the planned non-utility nuclear spin-off transaction.

Geographic Areas

For the years ended December 31, 2011 and 2010, the amount of revenue Entergy derived from outside of the United States was insignificant. As of December 31, 2011 and 2010, Entergy had no long-lived assets located outside of the United States.

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Registrant Subsidiaries

Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

NOTE 14. EQUITY METHOD INVESTMENTS (Entergy Corporation)

As of December 31, 2011, Entergy owns investments in the following companies that it accounts for under the equity method of accounting:

Investment	Ownership	Description

Entergy-Koch	50% partnership interest	Entergy-Koch was in the energy commodity marketing and trading business and gas transportation and storage business until the fourth quarter 2004 when these businesses were sold.

RS Cogen LLC	50% member interest	Co-generation project that produces power and steam on an industrial and merchant basis in the Lake Charles, Louisiana area.

Top Deer	50% member interest	Wind-powered electric generation joint venture.

Following is a reconciliation of Entergy’s investments in equity affiliates:

	2011	2010	2009
	(In Thousands)

Beginning of year	$40,697	$39,580	$66,247
Loss from the investments	(88)	(2,469)	(7,793)
Dispositions and other adjustments	4,267	3,586	(18,874)
End of year	$44,876	$40,697	$39,580

Transactions with equity method investees

Entergy Gulf States Louisiana purchased approximately $41.1 million, $50.8 million, and $49.3 million of electricity generated from Entergy’s share of RS Cogen in 2011, 2010, and 2009, respectively. Entergy’s operating transactions with its other equity method investees were not significant in 2011, 2010, or 2009.

NOTE 15. ACQUISITIONS AND DISPOSITIONS (Entergy Corporation and Entergy Louisiana)

Acquisitions

Acadia

In April 2011, Entergy Louisiana purchased Unit 2 of the Acadia Energy Center, a 580 MW generating unit located near Eunice, Louisiana, from an independent power producer. The Acadia Energy Center, which entered commercial service in 2002, consists of two combined-cycle gas-fired generating units, each nominally rated at 580 MW. Entergy Louisiana purchased 100 percent of Acadia Unit 2 and a 50 percent ownership interest in the facility’s

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common assets for approximately $300 million. In a separate transaction, Cleco Power acquired Acadia Unit 1 and the other 50 percent interest in the facility’s common assets. Cleco Power will serve as operator for the entire facility. The FERC and the LPSC approved the transaction.

Rhode Island State Energy Center

In December 2011 a subsidiary in the Entergy Wholesale Commodities business segment purchased the Rhode Island State Energy Center, a 583 MW natural gas-fired combined-cycle generating plant located in Johnston, Rhode Island, from a subsidiary of NextEra Energy Resources, for approximately $346 million. The Rhode Island State Energy Center began commercial operation in 2002.

Palisades Purchased Power Agreement

Entergy’s purchase of the Palisades plant in 2007 included a unit-contingent, 15-year purchased power agreement (PPA) with Consumers Energy for 100% of the plant’s output, excluding any future uprates. Prices under the PPA range from $43.50/MWh in 2007 to $61.50/MWh in 2022, and the average price under the PPA is $51/MWh. For the PPA, which was at below-market prices at the time of the acquisition, Entergy will amortize a liability to revenue over the life of the agreement. The amount that will be amortized each period is based upon the difference between the present value calculated at the date of acquisition of each year’s difference between revenue under the agreement and revenue based on estimated market prices. Amounts amortized to revenue were $43 million in 2011, $46 million in 2010, and $53 million in 2009. The amounts to be amortized to revenue for the next five years will be $17 million in 2012, $18 million for 2013, $16 million for 2014, $15 million for 2015, and $13 million for 2016.

NYPA Value Sharing Agreements

Entergy’s purchase of the FitzPatrick and Indian Point 3 plants from NYPA included value sharing agreements with NYPA. In October 2007, Entergy subsidiaries and NYPA amended and restated the value sharing agreements to clarify and amend certain provisions of the original terms. Under the amended value sharing agreements, Entergy subsidiaries will make annual payments to NYPA based on the generation output of the Indian Point 3 and FitzPatrick plants from January 2007 through December 2014. Entergy subsidiaries will pay NYPA $6.59 per MWh for power sold from Indian Point 3, up to an annual cap of $48 million, and $3.91 per MWh for power sold from FitzPatrick, up to an annual cap of $24 million. The annual payment for each year’s output is due by January 15 of the following year. Entergy will record the liability for payments to NYPA as power is generated and sold by Indian Point 3 and FitzPatrick. An amount equal to the liability will be recorded to the plant asset account as contingent purchase price consideration for the plants. In 2011, 2010, and 2009, Entergy Wholesale Commodities recorded $72 million as plant for generation during each of those years. This amount will be depreciated over the expected remaining useful life of the plants.

Dispositions

Harrison County

In the fourth quarter 2010, an Entergy Wholesale Commodities subsidiary sold its ownership interest in the Harrison County Power Project 550 MW combined-cycle plant to two Texas electric cooperatives that owned a minority share of the Marshall, Texas unit. Entergy sold its 61 percent share of the plant for $219 million and realized a gain of $44.2 million ($27.2 million net-of-tax) on the sale.

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NOTE 16. RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Market and Commodity Risks

In the normal course of business, Entergy is exposed to a number of market and commodity risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular instrument or commodity. All financial and commodity-related instruments, including derivatives, are subject to market risk. Entergy is subject to a number of commodity and market risks, including:

Type of Risk		Affected Businesses

Power price risk		Utility, Entergy Wholesale Commodities
Fuel price risk		Utility, Entergy Wholesale Commodities
Foreign currency exchange rate risk		Entergy Wholesale Commodities
Equity price and interest rate risk - investments		Utility, Entergy Wholesale Commodities

Entergy manages a portion of these risks using derivative instruments, some of which are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sales transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity futures, forwards, swaps, and options; and interest rate swaps. Entergy will occasionally enter into financially settled option contracts to manage market risk under certain hedging transactions which may or may not be designated as hedging instruments. Entergy enters into derivatives only to manage natural risks inherent in its physical or financial assets or liabilities.

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Gulf States Louisiana, Entergy Louisiana, and Entergy New Orleans) and Entergy Mississippi primarily through the purchase of short-term natural gas swaps. These swaps are marked-to-market with offsetting regulatory assets or liabilities. The notional volumes of these swaps are based on a portion of projected annual exposure to gas for electric generation and projected winter purchases for gas distribution at Entergy Gulf States Louisiana and Entergy New Orleans.

Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives.

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Derivatives

The fair values of Entergy’s derivative instruments on the consolidated balance sheets as of December 31, 2011 are as follows:

Instrument	Balance Sheet Location	Fair Value (a)	Offset (a)	Business

Derivatives designated as hedging instruments

Assets:
Electricity forwards, swaps and options	Prepayments and other (current portion)	$197 million	($25) million	Entergy Wholesale Commodities
Electricity forwards, swaps and options	Other deferred debits and other assets (non-current portion)	$112 million	($1) million	Entergy Wholesale Commodities

Liabilities:
Electricity forwards, swaps and options	Other current liabilities (current portion)	$-	($-)	Entergy Wholesale Commodities
Electricity forwards, swaps and options	Other non-current liabilities (non-current portion)	$1 million	($1) million	Entergy Wholesale Commodities

Derivatives not designated as hedging instruments

Assets:
Electricity forwards, swaps and options	Prepayments and other (current portion)	$37 million	($8) million	Entergy Wholesale Commodities
Electricity forwards, swaps and options	Other deferred debits and other assets (non-current portion)	$-	($-)	Entergy Wholesale Commodities

Liabilities:
Electricity forwards, swaps and options	Other current liabilities (current portion)	$33 million	($33) million	Entergy Wholesale Commodities
Electricity forwards, swaps and options	Other non-current liabilities (non-current portion)	$-	($-)	Entergy Wholesale Commodities
Natural gas swaps	Other current liabilities	$30 million	($-)	Utility

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The fair values of Entergy’s derivative instruments on the consolidated balance sheets as of December 31, 2010 are as follows:

Instrument	Balance Sheet Location	Fair Value (a)	Offset (a)	Business

Derivatives designated as hedging instruments

Assets:
Electricity forwards, swaps and options	Prepayments and other (current portion)	$160 million	($7) million	Entergy Wholesale Commodities
Electricity forwards, swaps and options	Other deferred debits and other assets (non-current portion)	$82 million	($29) million	Entergy Wholesale Commodities

Liabilities:
Electricity forwards, swaps and options	Other current liabilities (current portion)	$5 million	($5) million	Entergy Wholesale Commodities
Electricity forwards, swaps and options	Other non-current liabilities (non-current portion)	$47 million	($30) million	Entergy Wholesale Commodities

Derivatives not designated as hedging instruments

Assets:
Electricity forwards, swaps and options	Prepayments and other (current portion)	$2 million	($-)	Entergy Wholesale Commodities
Electricity forwards, swaps and options	Other deferred debits and other assets (non-current portion)	$14 million	($8) million	Entergy Wholesale Commodities

Liabilities:
Electricity forwards, swaps and options	Other current liabilities (current portion)	$2 million	($2) million	Entergy Wholesale Commodities
Electricity forwards, swaps and options	Other non-current liabilities (non-current portion)	$7 million	($7) million	Entergy Wholesale Commodities
Natural gas swaps	Other current liabilities	$2 million	($-)	Utility

(a)

The balances of derivative assets and liabilities in these tables are presented gross. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented on the Entergy Consolidated Balance Sheets on a net basis in accordance with accounting guidance for Derivatives and Hedging.

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Notes to Financial Statements

The effect of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the years ended December 31, 2011, 2010, and 2009 is as follows:

Instrument	Amount of gain recognized in AOCI (effective portion)	Income Statement location	Amount of gain reclassified from accumulated OCI into income (effective portion)

2011
Electricity forwards, swaps and options	$296 million	Competitive businesses operating revenues	$168 million

2010
Electricity forwards, swaps and options	$206 million	Competitive businesses operating revenues	$220 million

2009
Electricity forwards, swaps, and options	$315 million	Competitive businesses operating revenues	$322 million

Electricity over-the-counter instruments that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation. Based on market prices as of December 31, 2011, cash flow hedges relating to power sales totaled $310 million of net unrealized gains. Approximately $197 million is expected to be reclassified from accumulated other comprehensive income (OCI) to operating revenues in the next twelve months. The actual amount reclassified from accumulated OCI, however, could vary due to future changes in market prices. Gains totaling approximately $168 million, $220 million, and $322 million were realized on the maturity of cash flow hedges, before taxes of $59 million, $77 million, and $113 million for the years ended December 31, 2011, 2010, and 2009, respectively. Unrealized gains or losses recorded in OCI result from hedging power output at the Entergy Wholesale Commodities power plants. The related gains or losses from hedging power are included in operating revenues when realized. The maximum length of time over which Entergy is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at December 31, 2011 is approximately three years. Planned generation currently sold forward from Entergy Wholesale Commodities nuclear power plants is 88% for 2012 of which approximately 47% is sold under financial derivatives and the remainder under normal purchase/sale contracts. The change in the value of Entergy’s cash flow hedges due to ineffectiveness was $6.1 million for the year ended December 31, 2011 and was insignificant for the year ended December 31, 2010. The ineffective portion of cash flow hedges is recorded in competitive business operating revenues. Certain agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide collateral to secure its obligations when the current market prices exceed the contracted power prices. The primary form of collateral to satisfy these requirements is an Entergy Corporation guaranty. As of December 31, 2011, there were no hedge contracts with counterparties in a liability position. Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge. In this situation, gains or losses accumulated in OCI prior to de-designation continue to be deferred in OCI until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings.

Natural gas over-the-counter swaps that financially settle against NYMEX futures are used to manage fuel price volatility for the Utility’s Louisiana and Mississippi customers. All benefits or costs of the program are recorded in fuel costs. The total volume of natural gas swaps outstanding as of December 31, 2011 is 37,980,000 MMBtu for Entergy, 10,890,000 MMBtu for Entergy Gulf States Louisiana, 15,730,000 MMBtu for Entergy Louisiana,

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10,360,000 MMBtu for Entergy Mississippi, and 1,000,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master agreements that do not require collateralization based on mark-to-market value, but do carry adequate assurance language that may lead to collateralization requests.

The effect of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the years ended December 31, 2011, 2010, and 2009 is as follows:

Instrument	Amount of gain recognized in AOCI	Income Statement location	Amount of gain (loss) recorded in income

2011
Natural gas swaps	$ -	Fuel, fuel-related expenses, and gas purchased for resale	($62) million
Electricity forwards, swaps and options de-designated as hedged items	$1 million	Competitive business operating revenues	$11 million

2010
Natural gas swaps	$ -	Fuel, fuel-related expenses, and gas purchased for resale	($95) million
Electricity forwards, swaps and options de-designated as hedged items	$15 million	Competitive business operating revenues	$ -

2009
Natural gas swaps	$ -	Fuel, fuel-related expenses, and gas purchased for resale	($160) million

Due to regulatory treatment, the natural gas swaps are marked to market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.

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Notes to Financial Statements

The fair values of the Registrant Subsidiaries’ derivative instruments on their balance sheets as of December 31, 2011 and 2010 are as follows:

Instrument	Balance Sheet Location	Fair Value	Registrant

Derivatives not designated as hedging instruments

2011
Liabilities:
Natural gas swaps	Gas hedge contracts	$8.6 million	Entergy Gulf States Louisiana
Natural gas swaps	Gas hedge contracts	$12.4 million	Entergy Louisiana
Natural gas swaps	Other current liabilities	$7.8 million	Entergy Mississippi
Natural gas swaps	Other current liabilities	$1.5 million	Entergy New Orleans

2010
Assets:
Natural gas swaps	Prepayments and other	$0.3 million	Entergy Mississippi

Liabilities:
Natural gas swaps	Gas hedge contracts	$1.0 million	Entergy Gulf States Louisiana
Natural gas swaps	Gas hedge contracts	$0.4 million	Entergy Louisiana
Natural gas swaps	Other current liabilities	$0.5 million	Entergy New Orleans

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their statements of income for the years ended December 31, 2011, 2010, and 2009 are as follows:

Instrument	Statement of Income Location	Amount of loss recorded in income	Registrant

2011
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($17.9) million	Entergy Gulf States Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($25.6) million	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($15.0) million	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($3.2) million	Entergy New Orleans

2010
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($25.0) million	Entergy Gulf States Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($40.5) million	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($27.5) million	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($1.7) million	Entergy New Orleans

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Notes to Financial Statements

Instrument	Statement of Income Location	Amount of loss recorded in income	Registrant

2009
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($42.0) million	Entergy Gulf States Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($66.4) million	Entergy Louisiana
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($40.7) million	Entergy Mississippi
Natural gas swaps	Fuel, fuel-related expenses, and gas purchased for resale	($10.5) million	Entergy New Orleans

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments other than forward energy contracts held by competitive businesses are reflected in future rates and therefore do not accrue to the benefit or detriment of shareholders. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are:

Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents, debt instruments, and gas hedge contracts.

Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following:

-	quoted prices for similar assets or liabilities in active markets;

-	quoted prices for identical assets or liabilities in inactive markets;

-	inputs other than quoted prices that are observable for the asset or liability; or

-	inputs that are derived principally from or corroborated by observable market data by correlation or other means.

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Level 2 consists primarily of individually owned debt instruments or shares in common trusts. Common trust funds are stated at estimated fair value based on the fair market value of the underlying investments.

Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of derivative power contracts used as cash flow hedges of power sales at merchant power plants.

The values for the cash flow hedges that are recorded as derivative contract assets or liabilities are based on both observable inputs including public market prices and unobservable inputs such as model-generated prices for longer-term markets and are classified as Level 3 assets and liabilities. The amounts reflected as the fair value of derivative assets or liabilities are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable or payable by Entergy if the contracts were settled at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from Entergy’s Entergy Wholesale Commodities business. The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices and estimates regarding the costs associated with the transportation of the power from the plants’ bus bar to the contract’s point of delivery, generally a power market hub, for the period thereafter. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities. As of December 31, 2011, Entergy had in-the-money derivative contracts with a fair value of $312 million with counterparties or their guarantor who are all currently investment grade. As of December 31, 2011 there are no out-of-the-money contracts supported by corporate guarantees, which would require additional cash or letters of credit in the event of a decrease in Entergy Corporation’s credit rating to below investment grade.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2011 and December 31, 2010. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect their placement within the fair value hierarchy levels.

2011	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$613	$-	$-	$613
Decommissioning trust funds (a):
Equity securities	397	1,732	-	2,129
Debt securities	639	1,020	-	1,659
Power contracts	-	-	312	312
Securitization recovery trust account	50	-	-	50
Storm reserve escrow account	335	-	-	335
	$2,034	$2,752	$312	$5,098

Liabilities:
Gas hedge contracts	$30	$-	$-	$30

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2010	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$1,218	$-	$-	$1,218
Decommissioning trust funds (a):
Equity securities	387	1,689	-	2,076
Debt securities	497	1,023	-	1,520
Power contracts	-	-	214	214
Securitization recovery trust account	43	-	-	43
Storm reserve escrow account	329	-	-	329
	$2,474	$2,712	$214	$5,400

Liabilities:
Power contracts	$-	$-	$17	$17
Gas hedge contracts	2	-	-	2
	$2	$-	$17	$19

(a)

The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 17 for additional information on the investment portfolios.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the years ended December 31, 2011, 2010, and 2009:

	2011	2010	2009
	(In Millions)

Balance as of January 1,	$197	$200	$207

Unrealized gains from price changes	268	221	310
Unrealized gains/(losses) on originations	15	(4)	5
Realized gains on settlements	(168)	(220)	(322)

Balance as of December 31,	$312	$197	$200

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The following tables set forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets that are accounted for at fair value on a recurring basis as of December 31, 2011 and December 31, 2010. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

Entergy Arkansas

2011	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$17.9	$-	$-	$17.9
Decommissioning trust funds (a):
Equity securities	6.3	323.1	-	329.4
Debt securities	82.8	129.5	-	212.3
Securitization recovery trust account	3.9	-	-	3.9
	$110.9	$452.6	$-	$563.5

2010	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$101.9	$-	$-	$101.9
Decommissioning trust funds (a):
Equity securities	3.4	316.3	-	319.7
Debt securities	41.4	159.7	-	201.1
Securitization recovery trust account	2.4	-	-	2.4
	$149.1	$476.0	$-	$625.1

Entergy Gulf States Louisiana

2011	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$24.6	$-	$-	$24.6
Decommissioning trust funds (a):
Equity securities	5.1	233.6	-	238.7
Debt securities	39.5	142.7	-	182.2
Storm reserve escrow account	90.2	-	-	90.2
	$159.4	$376.3	$-	$535.7

Liabilities:
Gas hedge contracts	$8.6	$-	$-	$8.6

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2010	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$154.9	$-	$-	$154.9
Decommissioning trust funds (a):
Equity securities	3.8	231.1	-	234.9
Debt securities	32.2	126.5	-	158.7
Storm reserve escrow account	90.1	-	-	90.1
	$281.0	$357.6	$-	$638.6

Liabilities:
Gas hedge contracts	$1.0	$-	$-	$1.0

Entergy Louisiana

2011	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Decommissioning trust funds (a):
Equity securities	$2.9	$146.3	$-	$149.2
Debt securities	51.6	53.2	-	104.8
Securitization recovery trust account	5.2	-	-	5.2
Storm reserve escrow account	201.2	-	-	201.2
	$260.9	$199.5	$-	$460.4

Liabilities:
Gas hedge contracts	$12.4	$-	$-	$12.4

2010	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$122.5	$-	$-	$122.5
Decommissioning trust funds (a):
Equity securities	1.3	142.6	-	143.9
Debt securities	45.7	50.9	-	96.6
Storm reserve escrow account	201.0	-	-	201.0
	$370.5	$193.5	$-	$564.0

Liabilities:
Gas hedge contracts	$0.4	$-	$-	$0.4

Entergy Mississippi

2011	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Storm reserve escrow account	$31.8	$-	$-	$31.8

Liabilities:
Gas hedge contracts	$7.8	$-	$-	$7.8

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2010	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Gas hedge contracts	$0.3	$-	$-	$0.3
Storm reserve escrow account	31.9	-	-	31.9
	$32.2	$-	$-	$32.2

Entergy New Orleans

2011	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$9.3	$-	$-	$9.3
Storm reserve escrow account	12.0	-	-	12.0
	$21.3	$-	$-	$21.3

Liabilities:
Gas hedge contracts	$1.5	$-	$-	$1.5

2010	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$53.6	$-	$-	$53.6
Storm reserve escrow account	6.0	-	-	6.0
	$59.6	$-	$-	$59.6

Liabilities:
Gas hedge contracts	$0.5	$-	$-	$0.5

Entergy Texas

2011	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$65.1	$-	$-	$65.1
Securitization recovery trust account	41.2	-	-	41.2
	$106.3	$-	$-	$106.3

2010	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$33.6	$-	$-	$33.6
Securitization recovery trust account	40.6	-	-	40.6
	$74.2	$-	$-	$74.2

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System Energy

2011	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$154.2	$-	$-	$154.2
Decommissioning trust funds (a):
Equity securities	2.7	234.5	-	237.2
Debt securities	123.2	63.0	-	186.2
	$280.1	$297.5	$-	$577.6

2010	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$262.9	$-	$-	$262.9
Decommissioning trust funds (a):
Equity securities	3.1	220.9	-	224.0
Debt securities	95.7	68.2	-	163.9
	$361.7	$289.1	$-	$650.8

(a)

NOTE 17. DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy)

Entergy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The NRC requires Entergy subsidiaries to maintain trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades (NYPA currently retains the decommissioning trusts and liabilities for Indian Point 3 and FitzPatrick). The funds are invested primarily in equity securities; fixed-rate, fixed-income securities; and cash and cash equivalents.

Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets. For the nonregulated portion of River Bend, Entergy Gulf States Louisiana has recorded an offsetting amount of unrealized gains/(losses) in other deferred credits. Decommissioning trust funds for Pilgrim, Indian Point 2, Vermont Yankee, and Palisades do not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains recorded on the assets in these trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity because these assets are classified as available for sale. Unrealized losses (where cost exceeds fair market value) on the assets in these trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. Generally, Entergy records realized gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities.

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The securities held as of December 31, 2011 and 2010 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)

2011
Equity Securities	$2,129	$423	$14
Debt Securities	1,659	115	5
Total	$3,788	$538	$19

2010
Equity Securities	$2,076	$436	$9
Debt Securities	1,520	67	12
Total	$3,596	$503	$21

Deferred taxes on unrealized gains/(losses) are recorded in other comprehensive income for the decommissioning trusts which do not meet the criteria for regulatory accounting treatment as described above. Unrealized gains/(losses) above are reported before deferred taxes of $149 million and $130 million as of December 31, 2011 and 2010, respectively. The amortized cost of debt securities was $1,530 million as of December 31, 2011 and $1,475 million as of December 31, 2010. As of December 31, 2011, the debt securities have an average coupon rate of approximately 4.15%, an average duration of approximately 5.40 years, and an average maturity of approximately 8.53 years. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index.

The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2011:

	Equity Securities		Debt Securities
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)

Less than 12 months	$130	$9	$123	$3
More than 12 months	43	5	60	2
Total	$173	$14	$183	$5

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	Equity Securities		Debt Securities
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)

Less than 12 months	$15	$1	$474	$11
More than 12 months	105	8	4	1
Total	$120	$9	$478	$12

The unrealized losses in excess of twelve months on equity securities above relate to Entergy’s Utility operating companies and System Energy.

The fair value of debt securities, summarized by contractual maturities, as of December 31, 2011 and 2010 are as follows:

	2011	2010
	(In Millions)
less than 1 year	$69	$37
1 year - 5 years	566	557
5 years - 10 years	583	512
10 years - 15 years	187	163
15 years - 20 years	42	47
20 years+	212	204
Total	$1,659	$1,520

During the years ended December 31, 2011, 2010, and 2009, proceeds from the dispositions of securities amounted to $1,360 million, $2,606 million, and $2,571 million, respectively. During the years ended December 31, 2011, 2010, and 2009, gross gains of $29 million, $69 million, and $80 million, respectively, and gross losses of $11 million, $9 million, and $30 million, respectively, were reclassified out of other comprehensive income into earnings.

Entergy Arkansas

Entergy Arkansas holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of December 31, 2011 and 2010 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2011
Equity Securities	$329.4	$70.9	$0.4
Debt Securities	212.3	15.2	0.4
Total	$541.7	$86.1	$0.8

2010
Equity Securities	$319.7	$74.2	$0.3
Debt Securities	201.1	11.0	1.0
Total	$520.8	$85.2	$1.3

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Notes to Financial Statements

The amortized cost of debt securities was $197.5 million as of December 31, 2011 and $191.2 million as of December 31, 2010. As of December 31, 2011, the debt securities have an average coupon rate of approximately 3.61%, an average duration of approximately 4.86 years, and an average maturity of approximately 5.58 years. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

	Equity Securities		Debt Securities
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)

Less than 12 months	$13.7	$0.4	$14.3	$0.4
More than 12 months	-	-	1.0	-
Total	$13.7	$0.4	$15.3	$0.4

	Equity Securities		Debt Securities
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)

Less than 12 months	$-	$-	$44.3	$1.0
More than 12 months	6.6	0.3	-	-
Total	$6.6	$0.3	$44.3	$1.0

The fair value of debt securities, summarized by contractual maturities, as of December 31, 2011 and 2010 are as follows:

	2011	2010
	(In Millions)

less than 1 year	$7.8	$5.3
1 year - 5 years	86.5	100.1
5 years - 10 years	109.1	85.2
10 years - 15 years	2.7	4.5
15 years - 20 years	-	-
20 years+	6.2	6.0
Total	$212.3	$201.1

During the years ended December 31, 2011, 2010, and 2009, proceeds from the dispositions of securities amounted to $125.4 million, $367.3 million, and $154.6 million, respectively. During the years ended December 31, 2011, 2010, and 2009, gross gains of $3.9 million, $29.2 million, and $2.6 million, respectively, and gross losses of $0.2 million, $0.8 million, and $1.4 million, respectively, were recorded in earnings.

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Entergy Gulf States Louisiana

Entergy Gulf States Louisiana holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of December 31, 2011 and 2010 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2011
Equity Securities	$238.7	$40.9	$0.8
Debt Securities	182.2	15.2	0.3
Total	$420.9	$56.1	$1.1

2010
Equity Securities	$234.9	$41.7	$1.4
Debt Securities	158.7	8.8	0.8
Total	$393.6	$50.5	$2.2

The amortized cost of debt securities was $166.9 million as of December 31, 2011 and $150.0 million as of December 31, 2010. As of December 31, 2011, the debt securities have an average coupon rate of approximately 4.74%, an average duration of approximately 5.94 years, and an average maturity of approximately 9.20 years. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

	Equity Securities		Debt Securities
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)

Less than 12 months	$14.0	$0.5	$9.3	$0.2
More than 12 months	2.7	0.3	1.1	0.1
Total	$16.7	$0.8	$10.4	$0.3

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	Equity Securities		Debt Securities
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)

Less than 12 months	$-	$-	$22.6	$0.6
More than 12 months	18.6	1.4	0.9	0.2
Total	$18.6	$1.4	$23.5	$0.8

The fair value of debt securities, summarized by contractual maturities, as of December 31, 2011 and 2010 are as follows:

	2011	2010
	(In Millions)

less than 1 year	$7.1	$4.7
1 year - 5 years	40.8	35.0
5 years - 10 years	53.5	54.2
10 years - 15 years	62.9	48.1
15 years - 20 years	3.2	3.7
20 years+	14.7	13.0
Total	$182.2	$158.7

During the years ended December 31, 2011, 2010, and 2009, proceeds from the dispositions of securities amounted to $76.8 million, $100.8 million, and $95.2 million, respectively. During the years ended December 31, 2011, 2010, and 2009, gross gains of $2.8 million, $2.0 million, and $2.4 million, respectively, and gross losses of $0.5 million, $0.4 million, and $0.6 million, respectively, were recorded in earnings.

Entergy Louisiana

Entergy Louisiana holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of December 31, 2011 and 2010 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2011
Equity Securities	$149.2	$29.7	$1.6
Debt Securities	104.8	8.8	0.2
Total	$254.0	$38.5	$1.8

2010
Equity Securities	$143.9	$31.0	$1.7
Debt Securities	96.6	5.3	0.1
Total	$240.5	$36.3	$1.8

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Notes to Financial Statements

The amortized cost of debt securities was $91.9 million as of December 31, 2011 and $91.0 million as of December 31, 2010. As of December 31, 2011, the debt securities have an average coupon rate of approximately 3.81%, an average duration of approximately 4.94 years, and an average maturity of approximately 8.96 years. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

	Equity Securities		Debt Securities
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)

Less than 12 months	$11.6	$0.3	$5.5	$0.2
More than 12 months	10.0	1.3	0.2	-
Total	$21.6	$1.6	$5.7	$0.2

	Equity Securities		Debt Securities
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)

Less than 12 months	$-	$-	$4.8	$0.1
More than 12 months	18.9	1.7	0.2	-
Total	$18.9	$1.7	$5.0	$0.1

The fair value of debt securities, summarized by contractual maturities, as of December 31, 2011 and 2010 are as follows:

	2011	2010
	(In Millions)

less than 1 year	$3.9	$5.3
1 year - 5 years	39.8	28.1
5 years - 10 years	22.2	31.5
10 years - 15 years	18.9	14.1
15 years - 20 years	2.2	2.9
20 years+	17.8	14.7
Total	$104.8	$96.6

During the years ended December 31, 2011, 2010, and 2009, proceeds from the dispositions of securities amounted to $19.9 million, $44.5 million, and $47.5 million, respectively. During the years ended December 31, 2011, 2010, and 2009, gross gains of $0.3 million, $0.7 million, and $1.7 million, respectively, and gross losses of $0.2 million, $0.3 million, and $1.1 million, respectively, were recorded in earnings.

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Notes to Financial Statements

System Energy

System Energy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held as of December 31, 2011 and 2010 are summarized as follows:

	Fair Value	Total Unrealized Gains	Total Unrealized Losses
	(In Millions)
2011
Equity Securities	$237.2	$35.4	$5.4
Debt Securities	186.2	9.5	0.1
Total	$423.4	$44.9	$5.5

2010
Equity Securities	$224.0	$37.3	$5.2
Debt Securities	163.9	4.4	1.5
Total	$387.9	$41.7	$6.7

The amortized cost of debt securities was $175.1 million as of December 31, 2011 and $159.3 million as of December 31, 2010. As of December 31, 2011, the debt securities have an average coupon rate of approximately 3.46%, an average duration of approximately 4.89 years, and an average maturity of approximately 6.91 years. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively small percentage of the securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

	Equity Securities		Debt Securities
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)

Less than 12 months	$41.3	$1.8	$10.5	$0.1
More than 12 months	30.0	3.6	-	-
Total	$71.3	$5.4	$10.5	$0.1

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Notes to Financial Statements

	Equity Securities		Debt Securities
	Fair Value	Gross Unrealized Losses	Fair Value	Gross Unrealized Losses
	(In Millions)

Less than 12 months	$-	$-	$63.0	$1.5
More than 12 months	61.1	5.2	-	-
Total	$61.1	$5.2	$63.0	$1.5

The fair value of debt securities, summarized by contractual maturities, as of December 31, 2011 and 2010 are as follows:

	2011	2010
	(In Millions)

less than 1 year	$10.2	$1.8
1 year - 5 years	94.6	79.8
5 years - 10 years	57.9	52.3
10 years - 15 years	2.6	2.5
15 years - 20 years	2.9	3.8
20 years+	18.0	23.7
Total	$186.2	$163.9

During the years ended December 31, 2011, 2010, and 2009, proceeds from the dispositions of securities amounted to $203.4 million, $322.8 million, and $393.0 million, respectively. During the years ended December 31, 2011, 2010, and 2009, gross gains of $2.7 million, $4.4 million, and $4.4 million, respectively, and gross losses of $1.2 million, $0.6 million, and $6.5 million, respectively, were recorded in earnings.

Other-than-temporary impairments and unrealized gains and losses

Entergy, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy evaluate unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred. The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss). For debt securities held as of January 1, 2009 for which an other-than-temporary impairment had previously been recognized but for which assessment under the new guidance indicates this impairment is temporary, Entergy recorded an adjustment to its opening balance of retained earnings of $11.3 million ($6.4 million net-of-tax). Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the years ended December 31, 2011 and 2010. The assessment of whether an investment in an equity security has suffered an other-than-temporary impairment continues to be based on a number of factors including, first, whether Entergy has the ability and intent to hold the investment to recover its value, the duration and severity of any losses, and, then, whether it is expected that the investment will recover its value within a reasonable period of time. Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. Entergy recorded charges to other income of $0.1 million in 2011, $1 million in 2010, and $86 million in 2009, resulting from the recognition of the other-than-temporary impairment of certain equity securities held in its decommissioning trust funds.

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Notes to Financial Statements

NOTE 18. VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Under applicable authoritative accounting guidance, a variable interest entity (VIE) is an entity that conducts a business or holds property that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or where equity holders do not receive expected losses or returns. An entity may have an interest in a VIE through ownership or other contractual rights or obligations, and is required to consolidate a VIE if it is the VIE’s primary beneficiary.

The FASB issued authoritative accounting guidance that became effective in the first quarter 2010 that revised the manner in which entities evaluate whether consolidation is required for VIEs. Under the revised guidance, the primary beneficiary of a VIE is the entity that has the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance, and has the obligation to absorb losses or has the right to residual returns that would potentially be significant to the entity. In conjunction with the adoption of the new guidance, Entergy updated reviews of its contracts and arrangements to determine whether Entergy is the primary beneficiary of a VIE based on the revisions to the previous consolidation model and other provisions of this standard. Based on this review Entergy determined that Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy should consolidate the respective companies from which they lease nuclear fuel, usually in a sale and leaseback transaction. This determination is because Entergy directs the nuclear fuel companies with respect to nuclear fuel purchases, assists the nuclear fuel companies in obtaining financing, and, if financing cannot be arranged, the lessee (Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, or System Energy) is responsible to repurchase nuclear fuel to allow the nuclear fuel company (the VIE) to meet its obligations. Under the previous guidance, the determination of the primary beneficiary of a VIE was based on ownership interests and the risks and rewards in the entity attributable to the variable interest holders. Therefore, the Entergy companies did not previously consolidate the nuclear fuel companies. Because Entergy has historically accounted for the leases with the nuclear fuel companies as capital lease obligations, the effect of consolidating the nuclear fuel companies did not materially affect Entergy’s financial statements. During the term of the arrangements, none of the Entergy operating companies have been required to provide financial support apart from their scheduled lease payments. See Note 4 to the financial statements for details of the nuclear fuel companies’ credit facility and commercial paper borrowings and long-term debt that are reported by Entergy, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy. These amounts also represent Entergy’s and the respective Registrant Subsidiary’s maximum exposure to losses associated with their respective interests in the nuclear fuel companies.

Entergy Texas determined that Entergy Gulf States Reconstruction Funding I, LLC, and Entergy Texas Restoration Funding, LLC, companies wholly-owned and consolidated by Entergy Texas, are variable interest entities and that Entergy Texas is the primary beneficiary. In June 2007, Entergy Gulf States Reconstruction Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Rita reconstruction costs. In November 2009, Entergy Texas Restoration Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs. With the proceeds, the variable interest entities purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of the variable interest entities, including the transition property, and the creditors of the variable interest entities do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to the variable interest entities except to remit transition charge collections. See Note 5 to the financial statements for additional details regarding the securitization bonds.

Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, is a variable interest entity and Entergy Arkansas is the primary beneficiary. In August 2010, Entergy Arkansas Restoration Funding issued storm cost recovery bonds to finance Entergy Arkansas’s January 2009 ice storm damage restoration costs. With the proceeds, Entergy Arkansas Restoration Funding purchased from Entergy

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Arkansas the storm recovery property, which is the right to recover from customers through a storm recovery charge amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the consolidated Entergy Arkansas balance sheet. The creditors of Entergy Arkansas do not have recourse to the assets or revenues of Entergy Arkansas Restoration Funding, including the storm recovery property, and the creditors of Entergy Arkansas Restoration Funding do not have recourse to the assets or revenues of Entergy Arkansas. Entergy Arkansas has no payment obligations to Entergy Arkansas Restoration Funding except to remit storm recovery charge collections. See Note 5 to the financial statements for additional details regarding the storm cost recovery bonds.

Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by Entergy Louisiana, is a variable interest entity and Entergy Louisiana is the primary beneficiary. In September 2011, Entergy Louisiana Investment Recovery Funding issued investment recovery bonds to recover Entergy Louisiana’s investment recovery costs associated with the cancelled Little Gypsy repowering project. With the proceeds, Entergy Louisiana Investment Recovery Funding purchased from Entergy Louisiana the investment recovery property, which is the right to recover from customers through an investment recovery charge amounts sufficient to service the bonds. The investment recovery property is reflected as a regulatory asset on the consolidated Entergy Louisiana balance sheet. The creditors of Entergy Louisiana do not have recourse to the assets or revenues of Entergy Louisiana Investment Recovery Funding, including the investment recovery property, and the creditors of Entergy Louisiana Investment Recovery Funding do not have recourse to the assets or revenues of Entergy Louisiana. Entergy Louisiana has no payment obligations to Entergy Louisiana Investment Recovery Funding except to remit investment recovery charge collections. See Note 5 to the financial statements for additional details regarding the investment recovery bonds.

Entergy Louisiana and System Energy are also considered to each hold a variable interest in the lessors from which they lease undivided interests representing approximately 9.3% of the Waterford 3 and 11.5% of the Grand Gulf nuclear plants, respectively. Entergy Louisiana and System Energy are the lessees under these arrangements, which are described in more detail in Note 10 to the financial statements. Entergy Louisiana made payments on its lease, including interest, of $50.4 million in 2011, $35.1 million in 2010, and $32.5 million in 2009. System Energy made payments on its lease, including interest, of $49.4 million in 2011, $48.6 million in 2010, and $47.8 million in 2009. The lessors are banks acting in the capacity of owner trustee for the benefit of equity investors in the transactions pursuant to trust agreements entered solely for the purpose of facilitating the lease transactions. It is possible that Entergy Louisiana and System Energy may be considered as the primary beneficiary of the lessors, but Entergy is unable to apply the revised authoritative accounting guidance with respect to these VIEs because the lessors are not required to, and could not, provide the necessary financial information to consolidate the lessors. Because Entergy accounts for these leasing arrangements as capital financings, however, Entergy believes that consolidating the lessors would not materially affect the financial statements. In the unlikely event of default under a lease, remedies available to the lessor include payment by the lessee of the fair value of the undivided interest in the plant, payment of the present value of the basic rent payments, or payment of a predetermined casualty value. Entergy believes, however, that the obligations recorded on the balance sheets materially represent each company’s potential exposure to loss.

Entergy has also reviewed various lease arrangements, power purchase agreements, and other agreements in which it holds a variable interest. In these cases, Entergy has determined that it is not the primary beneficiary of the related VIE because it does not have the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance, or it does not have the obligation to absorb losses or the right to residual returns that would potentially be significant to the entity, or both.

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Notes to Financial Statements

NOTE 19. TRANSACTIONS WITH AFFILIATES (Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; receive management, technical, and operating services from Entergy Operations; and until the first quarter 2011 purchased fuel from System Fuels. These transactions are on an “at cost” basis. In addition, Entergy Power sells electricity to Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans. RS Cogen sells electricity to Entergy Gulf States Louisiana.

As described in Note 1 to the financial statements, all of System Energy’s operating revenues consist of billings to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans.

As described in Note 4 to the financial statements, the Registrant Subsidiaries participate in Entergy’s money pool and earn interest income from the money pool. Entergy Arkansas, Entergy Mississippi, and Entergy New Orleans also received interest income from System Fuels until the first quarter 2011, when System Fuels repaid each company’s investment in System Fuels. As described in Note 2 to the financial statements, Entergy Gulf States Louisiana and Entergy Louisiana receive preferred membership distributions from Entergy Holdings Company.

The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates.

Intercompany Revenues

	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Millions)

2011	$293.8	$574.5	$139.0	$125.1	$96.9	$264.1	$563.4
2010	$307.1	$462.9	$228.0	$59.4	$56.0	$372.8	$558.6
2009	$354.5	$475.5	$260.2	$56.2	$87.6	$295.0	$554.0

Intercompany Operating Expenses

	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Millions)

	(1)	(2)	(3)		(4)
2011	$752.7	$563.1	$574.0	$337.2	$226.6	$486.6	$131.5
2010	$545.6	$602.7	$483.0	$372.9	$235.8	$519.0	$122.7
2009	$844.5	$547.6	$496.6	$353.1	$213.5	$417.6	$136.3

(1)	Includes $1.2 million in 2011, $0.1 million in 2010, and $0.1 million in 2009 for power purchased from Entergy Power.
(2)	Includes power purchased from RS Cogen of $41.1 million in 2011, $50.8 million in 2010, and $49.3 million in 2009.
(3)	Includes power purchased from Entergy Power of $14.5 million in 2011, $12.0 million in 2010, and $11.6 million in 2009.
(4)	Includes power purchased from Entergy Power of $14.2 million in 2011, $11.8 million in 2010, and $11.3 million in 2009.

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Notes to Financial Statements

Intercompany Interest and Investment Income

	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Millions)

2011	$0.1	$32.5	$78.1	$0.1	$0.1	$0.0	$0.6
2010	$0.6	$26.5	$67.6	$0.3	$0.2	$0.1	$0.7
2009	$0.9	$19.5	$55.5	$0.8	$0.7	$0.4	$1.9

NOTE 20. QUARTERLY FINANCIAL DATA (UNAUDITED) (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Operating results for the four quarters of 2011 and 2010 for Entergy Corporation and subsidiaries were:

	Operating Revenues	Operating Income	Consolidated Net Income	Net Income Attributable to Entergy Corporation
	(In Thousands)
2011:
First Quarter	$2,541,208	$510,891	$253,678	$248,663
Second Quarter	$2,803,279	$558,738	$320,598	$315,583
Third Quarter	$3,395,553	$600,909	$633,069	$628,054
Fourth Quarter	$2,489,033	$342,696	$160,027	$154,139
2010:
First Quarter	$2,759,347	$476,714	$218,814	$213,799
Second Quarter	$2,862,950	$626,241	$320,283	$315,266
Third Quarter	$3,332,176	$770,642	$497,901	$492,886
Fourth Quarter	$2,533,104	$393,780	$233,307	$228,291

Earnings per Average Common Share

	2011		2010
	Basic	Diluted	Basic	Diluted

First Quarter	$1.39	$1.38	$1.13	$1.12
Second Quarter	$1.77	$1.76	$1.67	$1.65
Third Quarter	$3.55	$3.53	$2.65	$2.62
Fourth Quarter	$0.88	$0.88	$1.27	$1.26

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Notes to Financial Statements

The business of the Utility operating companies is subject to seasonal fluctuations with the peak periods occurring during the third quarter. Operating results for the Registrant Subsidiaries for the four quarters of 2011 and 2010 were:

Operating Revenue

	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
2011:
First Quarter	$443,498	$495,898	$515,434	$288,983	$158,256	$348,884	$128,395
Second Quarter	$516,833	$522,562	$651,847	$302,194	$150,498	$444,423	$129,120
Third Quarter	$658,356	$596,948	$786,814	$365,569	$182,032	$556,955	$152,431
Fourth Quarter	$465,623	$519,001	$554,820	$309,724	$139,399	$406,937	$153,465
2010:
First Quarter	$531,894	$498,675	$611,524	$244,135	$180,026	$336,206	$128,584
Second Quarter	$540,535	$509,225	$619,473	$309,261	$138,685	$471,153	$124,419
Third Quarter	$575,062	$632,772	$768,190	$408,692	$189,698	$514,786	$151,781
Fourth Quarter	$434,956	$456,349	$539,579	$270,834	$151,040	$368,286	$153,800

Operating Income (Loss)

	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
2011:
First Quarter	$60,905	$83,069	$47,561	$37,286	$16,933	$45,593	$36,387
Second Quarter	$99,072	$89,860	$96,648	$50,280	$15,710	$57,682	$33,996
Third Quarter	$164,822	$100,276	($61,706)	$60,885	$36,603	$86,810	$38,520
Fourth Quarter	$33,555	$57,506	$3,606	$32,938	($6,118)	$24,935	$41,699
2010:
First Quarter	$41,917	$75,702	$56,328	$27,501	$21,479	$42,083	$38,396
Second Quarter	$108,793	$82,594	$90,115	$64,573	$10,027	$53,615	$42,292
Third Quarter	$166,575	$127,825	$120,872	$62,488	$26,356	$72,496	$42,033
Fourth Quarter	$8,731	$38,486	$29,359	$26,714	$3,970	$22,380	$42,426

Net Income (Loss)

	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
2011:
First Quarter	$25,608	$45,670	$40,298	$17,314	$8,927	$15,726	$19,336
Second Quarter	$50,298	$49,310	$75,103	$23,829	$8,207	$23,097	$21,986
Third Quarter	$80,945	$51,946	$337,722	$33,169	$18,943	$40,875	$14,263
Fourth Quarter	$8,040	$56,101	$20,800	$34,417	($101)	$1,147	$8,612
2010:
First Quarter	$15,253	$38,083	$36,833	$11,550	$11,517	$12,418	$20,613
Second Quarter	$55,401	$32,154	$61,259	$34,744	$5,529	$22,333	$20,442
Third Quarter	$93,290	$76,939	$94,320	$34,499	$15,540	$31,132	$22,299
Fourth Quarter	$8,674	$43,562	$39,023	$4,584	($1,472)	$317	$19,270

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Earnings Applicable to Common Equity

	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans
	(In Thousands)
2011:
First Quarter	$23,890	$45,464	$38,560	$16,607	$8,686
Second Quarter	$48,580	$49,104	$73,365	$23,122	$7,966
Third Quarter	$79,227	$51,740	$335,984	$32,462	$18,702
Fourth Quarter	$6,321	$55,894	$19,064	$33,710	($343)
2010:
First Quarter	$13,535	$37,877	$35,095	$10,843	$11,276
Second Quarter	$53,683	$31,946	$59,521	$34,037	$5,288
Third Quarter	$91,572	$76,733	$92,582	$33,792	$15,298
Fourth Quarter	$6,955	$43,355	$37,287	$3,877	($1,713)

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Part I Item 1

Entergy Corporation, Utility operating companies, and System Energy

ENTERGY’S BUSINESS

Entergy is an integrated energy company engaged primarily in electric power production and retail electric distribution operations. Entergy owns and operates power plants with approximately 30,000 MW of aggregate electric generating capacity, including over 10,000 MW of nuclear-fueled capacity. Entergy’s Utility business delivers electricity to 2.8 million utility customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy generated annual revenues of $11.2 billion in 2011 and had approximately 15,000 employees as of December 31, 2011.

Entergy operates primarily through two business segments: Utility and Entergy Wholesale Commodities.

The Utility business segment includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operates a small natural gas distribution business. As discussed in more detail in “Plan to Spin Off the Utility’s Transmission Business” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in December 2011, Entergy entered into an agreement to spin off its transmission business and merge it with a newly-formed subsidiary of ITC Holdings Corp.

See Note 13 to the financial statements for financial information regarding Entergy’s business segments.

Strategy

Entergy aspires to achieve industry-leading total shareholder returns in an environmentally responsible fashion by leveraging the scale and expertise inherent in its core nuclear and utility operations. Entergy’s current scope includes electricity generation, transmission and distribution as well as natural gas transportation and distribution. Entergy focuses on operational excellence with an emphasis on safety, reliability, customer service, sustainability, cost efficiency, and risk management. Entergy also focuses on portfolio management to make periodic buy, build, hold, or sell decisions based upon its analytically-derived points of view, which are updated as market conditions evolve.

Utility

The Utility business segment includes six wholly-owned retail electric utility subsidiaries: Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas. These companies generate, transmit, distribute and sell electric power to retail and wholesale customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy Gulf States Louisiana and Entergy New Orleans also provide natural gas utility services to customers in and around Baton Rouge, Louisiana, and New Orleans, Louisiana, respectively. Also included in the Utility is System Energy, a wholly-owned subsidiary of Entergy Corporation that owns or leases 90 percent of Grand Gulf. System Energy sells its power and capacity from Grand Gulf at wholesale to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans.

The six retail utility subsidiaries are each regulated by the FERC and by state utility commissions, or, in the case of Entergy New Orleans, the City Council. System Energy is regulated by the FERC because all of its transactions are at wholesale. The Utility continues to operate as a rate-regulated business as efforts toward deregulation have been abandoned or have not been initiated in its service territories. The overall generation portfolio of the Utility, which relies heavily on natural gas and nuclear generation, is consistent with Entergy’s strong support for the environment.

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Customers

As of December 31, 2011, the Utility operating companies provided retail electric and gas service to customers in Arkansas, Louisiana, Mississippi, and Texas, as follows:

		Electric Customers		Gas Customers
	Area Served	(In Thousands)	(%)	(In Thousands)	(%)

Entergy Arkansas	Portions of Arkansas	693	25%
Entergy Gulf States Louisiana	Portions of Louisiana	384	14%	92	48%
Entergy Louisiana	Portions of Louisiana	669	24%
Entergy Mississippi	Portions of Mississippi	437	16%
Entergy New Orleans	City of New Orleans*	161	6%	101	52%
Entergy Texas	Portions of Texas	413	15%
Total customers		2,757	100%	193	100%

*	Excludes the Algiers area of the city, where Entergy Louisiana provides electric service.

Electric Energy Sales

The electric energy sales of the Utility operating companies are subject to seasonal fluctuations, with the peak sales period normally occurring during the third quarter of each year. On August 3, 2011, Entergy reached a 2011 peak demand of 22,387 MWh, compared to the 2010 peak of 21,799 MWh recorded on August 2, 2010. Selected electric energy sales data is shown in the table below:

Selected 2011 Electric Energy Sales Data

	Entergy Arkansas	Entergy Gulf States Louisiana	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy	Entergy (a)
	(In GWh)
Sales to retail customers	21,584	19,885	31,744	13,574	5,120	16,863	-	108,688
Sales for resale:
Affiliates	6,893	8,595	2,145	431	1,167	4,158	9,293	-
Others	1,304	1,013	185	332	19	1,258	-	4,111
Total	29,781	29,493	34,074	14,337	6,306	22,279	9,293	112,799

Average use per residential customer (kWh)	14,119	16,376	16,022	15,948	13,231	16,719	-	15,528

(a)	Includes the effect of intercompany eliminations.

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The following table illustrates the Utility operating companies’ 2011 combined electric sales volume as a percentage of total electric sales volume, and 2011 combined electric revenues as a percentage of total 2011 electric revenue, each by customer class.

Customer Class	% of Sales Volume	% of Revenue

Residential	32.5	38.8
Commercial	25.5	26.9
Industrial (a)	36.2	26.6
Governmental	2.2	2.4
Wholesale/Other	3.6	5.3

(a)	Major industrial customers are in the chemical, petroleum refining, and pulp and paper industries.

See “Selected Financial Data” for each of the Utility operating companies for the detail of their sales by customer class for 2007-2011.

Selected 2011 Natural Gas Sales Data

Entergy New Orleans and Entergy Gulf States Louisiana provide both electric power and natural gas to retail customers. Entergy New Orleans and Entergy Gulf States Louisiana sold 10,074,754 and 7,005,074 Mcf, respectively, of natural gas to retail customers in 2011. In 2011, 97% of Entergy Gulf States Louisiana’s operating revenue was derived from the electric utility business, and only 3% from the natural gas distribution business. For Entergy New Orleans, 84% of operating revenue was derived from the electric utility business and 16% from the natural gas distribution business in 2011. Following is data concerning Entergy New Orleans’s 2011 retail operating revenue sources.

Customer Class	Electric Operating Revenue	Natural Gas Revenue

Residential	42%	52%
Commercial	37%	24%
Industrial	7%	8%
Governmental/Municipal	14%	16%

Retail Rate Regulation

General (Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas)

Each Utility operating company regularly participates in retail rate proceedings. The status of material retail rate proceedings is described in Note 2 to the financial statements. Certain aspects of the Utility operating companies’ retail rate mechanisms are discussed below.

Entergy Arkansas

Fuel and Purchased Power Cost Recovery

Entergy Arkansas’s rate schedules include an energy cost recovery rider to recover fuel and purchased energy costs in monthly bills. The rider utilizes prior calendar year energy costs and projected energy sales for the twelve-month period commencing on April 1 of each year to develop an energy cost rate, which is redetermined annually and includes a true-up adjustment reflecting the over-recovery or under-recovery, including carrying charges, of the energy cost for the prior calendar year. The energy cost recovery rider tariff also allows an interim rate request depending upon the level of over- or under-recovery of fuel and purchased energy costs. In December 2007, the APSC issued an order stating that Entergy Arkansas’s energy cost recovery rider will remain in effect, and any future termination of the rider would be subject to eighteen months advance notice by the APSC, which would occur following notice and hearing.

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Storm Cost Recovery

See Note 2 to the financial statements for a discussion of proceedings regarding recovery of Entergy Arkansas’s storm restoration costs.

Entergy Gulf States Louisiana

Fuel Recovery

Entergy Gulf States Louisiana’s electric rates include a fuel adjustment clause designed to recover the cost of fuel and purchased power costs. The fuel adjustment clause contains a surcharge or credit for deferred fuel expense and related carrying charges arising from the monthly reconciliation of actual fuel costs incurred with fuel cost revenues billed to customers, including carrying charges.

To help stabilize electricity costs, Entergy Gulf States Louisiana received approval from the LPSC to hedge its exposure to natural gas price volatility through the use of financial instruments. Entergy Gulf States Louisiana hedges approximately one-third of the projected exposure to natural gas price changes for the gas used to serve its native electric load for all months of the year. The hedge quantity is reviewed on an annual basis.

Entergy Gulf States Louisiana’s gas rates include a purchased gas adjustment clause based on estimated gas costs for the billing month adjusted by a surcharge or credit that arises from an annual reconciliation of fuel costs incurred with fuel cost revenues billed to customers, including carrying charges.

To help stabilize retail gas costs, Entergy Gulf States Louisiana received approval from the LPSC to hedge its exposure to natural gas price volatility for its gas purchased for resale through the use of financial instruments. Entergy Gulf States Louisiana hedges approximately one-half of the projected natural gas volumes used to serve its natural gas customers for November through March. The hedge quantity is reviewed on an annual basis.

Storm Cost Recovery

See Note 2 to the financial statements for a discussion of Entergy Gulf States Louisiana’s filings to recover storm-related costs.

Entergy Louisiana

Fuel Recovery

Entergy Louisiana’s rate schedules include a fuel adjustment clause designed to recover the cost of fuel and purchased power costs. The fuel adjustment clause contains a surcharge or credit for deferred fuel expense and related carrying charges arising from the monthly reconciliation of actual fuel costs incurred with fuel cost revenues billed to customers, including carrying charges.

In the Delaney vs. Entergy Louisiana proceeding, the LPSC ordered Entergy Louisiana, beginning with the May 2000 fuel adjustment clause filing, to re-price costs flowed through its fuel adjustment clause related to the Evangeline gas contract so that the price included for fuel adjustment clause recovery shall thereafter be at the rate of the Henry Hub first of the month cash market price (as reported by the publication Inside FERC) plus $0.24 per mmBtu for the month for which the fuel adjustment clause is calculated, irrespective of the actual cost for the Evangeline contract quantity reflected in that month’s fuel adjustment clause. The Evangeline gas contract expires on January 1, 2013.

To help stabilize electricity costs, Entergy Louisiana received approval from the LPSC in 2001 to hedge its exposure to natural gas price volatility through the use of financial instruments. Entergy Louisiana hedges approximately one-third of the projected exposure to natural gas price changes for the gas used to serve its native electric load for all months of the year. The hedge quantity is reviewed on an annual basis.

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In September 2002, Entergy Louisiana settled a proceeding that concerned a contract entered into by Entergy Louisiana to purchase, through 2031, energy generated by a hydroelectric facility known as the Vidalia project. In the settlement, the LPSC approved Entergy Louisiana’s proposed treatment of the regulatory effect of the benefit from a tax accounting election related to that project. In general, the settlement permitted Entergy Louisiana to keep a portion of the tax benefit in exchange for bearing the risk associated with sustaining the tax treatment. See Note 8 to the financial statements for additional discussion of the obligations related to the Vidalia project and the sharing of tax benefits with customers.

Storm Cost Recovery

See Note 2 to the financial statements for a discussion of Entergy Louisiana’s filings to recover storm-related costs.

Entergy Mississippi

Fuel Recovery

Entergy Mississippi’s rate schedules include energy cost recovery riders to recover fuel and purchased energy costs. The rider utilizes projected energy costs filed quarterly by Entergy Mississippi to develop an energy cost rate. The energy cost rate is redetermined each calendar quarter and includes a true-up adjustment reflecting the over-recovery or under-recovery of the energy cost as of the second quarter preceding the redetermination. Entergy Mississippi’s fuel cost recoveries are subject to annual audits conducted pursuant to the authority of the MPSC.

Power Management Rider

The MPSC approved the purchase of the Attala power plant in November 2005. In December 2005, the MPSC issued an order approving the investment cost recovery through its power management rider and limited the recovery to a period that begins with the closing date of the purchase and ends the earlier of the date costs are incorporated into base rates or December 31, 2006. As a consequence of the events surrounding Entergy Mississippi’s ongoing efforts to recover storm restoration costs associated with Hurricane Katrina, in October 2006, the MPSC approved a revision to Entergy Mississippi’s power management rider. The revision has the effect of allowing Entergy Mississippi to recover the annual ownership costs of the Attala plant until such time as a general rate case is filed.

To help stabilize electricity costs, Entergy Mississippi received approval from the MPSC to hedge its exposure to natural gas price volatility through the use of financial instruments. Entergy Mississippi hedges approximately one-half of the projected exposure to natural gas price changes for the gas used to serve its native electric load for all months of the year. The hedge quantity is reviewed on an annual basis.

Storm Cost Recovery

Entergy Mississippi maintains a storm damage reserve pursuant to orders of the MPSC and consistent with the regulatory accounting requirements. Entergy Mississippi's storm damage reserve is funded through its storm damage rider schedule. In August 2011, Entergy Mississippi filed with the MPSC a notice of its intent to revise the storm damage rider schedule to recover over a 36-month period approximately $30 million and to increase the level of monthly accruals to the storm damage reserve from the current level of $750,000 per month to $1.75 million per month, and to increase the current level of the storm reserve cap during which funds will accrue from $15 million to $25 million. The cap is the level of the storm reserve balance at which monthly accruals would temporarily cease. The amounts of the monthly accruals and the cap have not been revised since 2001 and the current amounts do not reflect the costs of current storm restoration activities. Consideration of Entergy Mississippi’s notice is pending.

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Entergy New Orleans

Fuel Recovery

Entergy New Orleans’s gas rate schedules include a purchased gas adjustment to reflect estimated gas costs for the billing month, adjusted by a surcharge or credit similar to that included in the electric fuel adjustment clause, including carrying charges. In October 2005, the City Council approved modification of the current gas cost collection mechanism effective November 2005 in order to address concerns regarding its fluctuations, particularly during the winter heating season. The modifications are intended to minimize fluctuations in gas rates during the winter months.

To help stabilize retail gas costs, Entergy New Orleans received approval from the City Council to hedge its exposure to natural gas price volatility for its gas purchased for resale through the use of financial instruments. Entergy New Orleans hedges approximately one-half of the projected natural gas volumes used to serve its natural gas customers for November through March. The hedge quantity is reviewed on an annual basis.

Storm Cost Recovery

See Note 2 to the financial statements for a discussion of Entergy New Orleans’s efforts to recover storm-related costs.

Entergy Texas

Fuel Recovery

Entergy Texas’s rate schedules include a fixed fuel factor to recover fuel and purchased power costs, including carrying charges, that are not included in base rates. Semi-annual revisions of the fixed fuel factor are made in March and September based on the market price of natural gas and changes in fuel mix. The amounts collected under Entergy Texas’s fixed fuel factor and any interim surcharge or refund are subject to fuel reconciliation proceedings before the PUCT. The PUCT fuel cost reviews are discussed in Note 2 to the financial statements.

Storm Cost Recovery

See Note 2 to the financial statements for a discussion of proceedings regarding recovery of Entergy Texas’s storm restoration costs.

Electric Industry Restructuring

In June 2009, a law was enacted in Texas that requires Entergy Texas to cease all activities relating to Entergy Texas’s transition to competition. The law allows Entergy Texas to remain a part of the SERC Region, although it does not prevent Entergy Texas from joining another power region. The law provides that proceedings to certify a power region that Entergy Texas belongs to as a qualified power region can be initiated by the PUCT, or on motion by another party, when the conditions supporting such a proceeding exist. Under the new law, the PUCT may not approve a transition to competition plan for Entergy Texas until the expiration of four years from the PUCT’s certification of Entergy Texas’s power region. In response to the new law, Entergy Texas in June 2009 gave notice to the PUCT of the withdrawal of its previously filed transition to competition plan, and requested that its transition to competition proceeding be dismissed. In July 2009 the ALJ dismissed the proceeding.

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The new law also contains provisions that allow Entergy Texas take advantage of a cost recovery mechanism that permits annual filings for the recovery of reasonable and necessary expenditures for transmission infrastructure improvement and changes in wholesale transmission charges. This mechanism was previously available to other non-ERCOT Texas utility companies, but not to Entergy Texas.

In September 2011, the PUCT adopted a proposed rule implementing a Distribution Cost Recovery Factor to recover capital and capital-related costs related to distribution infrastructure. The Distribution Cost Recovery Factor permits utilities once per year to implement an increase in rates above amounts reflected in base rates to reflect depreciation expense, federal income tax and other taxes, and return on investment. The Distribution Cost Recovery Factor rider may be changed a maximum of four times between base rate cases, and expires in January 2017, unless otherwise extended by the Texas Legislature.

The new law further amends already existing law that had required Entergy Texas to propose for PUCT approval a tariff to allow eligible customers the ability to contract for competitive generation. The amending language in the new law provides, among other things, that: 1) the tariff shall not be implemented in a manner that harms the sustainability or competitiveness of manufacturers who choose not to participate in the tariff; 2) Entergy Texas shall “purchase competitive generation service, selected by the customer, and provide the generation at retail to the customer” and 3) Entergy Texas shall provide and price transmission service and ancillary services under that tariff at a rate that is unbundled from its cost of service. The new law directs that the PUCT may not issue an order on the tariff that is contrary to an applicable decision, rule, or policy statement of a federal regulatory agency having jurisdiction.

Entergy Texas and the other parties to the PUCT proceeding to determine the design of the competitive generation tariff were involved in negotiations throughout 2011 with the objective of resolving as many disputed issues as possible regarding the tariff. While these negotiations remain pending, the PUCT has directed the parties to file testimony allowing it to consider and resolve certain threshold issues related to the design of the program, including: 1) the definition and calculation of any cost unrecovered by Entergy Texas as a result of the tariff; 2) who should be eligible to take service under the tariff; and 3) what ratepayers should be responsible for paying any unrecovered costs experienced by Entergy Texas. Testimony addressing these issues has been submitted and a hearing is scheduled for April 2012.

Franchises

Entergy Arkansas holds exclusive franchises to provide electric service in approximately 307 incorporated cities and towns in Arkansas. These franchises are unlimited in duration and continue unless the municipalities purchase the utility property. In Arkansas, franchises are considered to be contracts and, therefore, are terminable pursuant to the terms of the franchise agreement and applicable statutes.

Entergy Gulf States Louisiana holds non-exclusive franchises to provide electric service in approximately 56 incorporated municipalities and the unincorporated areas of approximately 18 parishes, and to provide gas service in the City of Baton Rouge and the unincorporated areas of two parishes. Most of Entergy Gulf States Louisiana’s franchises have a term of 60 years. Entergy Gulf States Louisiana’s current electric franchises expire during 2015-2046.

Entergy Louisiana holds non-exclusive franchises to provide electric service in approximately 116 incorporated Louisiana municipalities. Most of these franchises have 25-year terms. Entergy Louisiana also supplies electric service in approximately 45 Louisiana parishes in which it holds non-exclusive franchises. Entergy Louisiana’s electric franchises expire during 2015-2036.

Entergy Mississippi has received from the MPSC certificates of public convenience and necessity to provide electric service to areas within 45 counties, including a number of municipalities, in western Mississippi. Under Mississippi statutory law, such certificates are exclusive. Entergy Mississippi may continue to serve in such municipalities upon payment of a statutory franchise fee, regardless of whether an original municipal franchise is still in existence.

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Entergy New Orleans provides electric and gas service in the City of New Orleans pursuant to indeterminate permits set forth in city ordinances (except electric service in Algiers, which is provided by Entergy Louisiana). These ordinances contain a continuing option for the City of New Orleans to purchase Entergy New Orleans’s electric and gas utility properties.

Entergy Texas holds a certificate of convenience and necessity from the PUCT to provide electric service to areas within approximately 27 counties in eastern Texas, and holds non-exclusive franchises to provide electric service in approximately 68 incorporated municipalities. Entergy Texas was typically granted 50-year franchises, but recently has been receiving 25-year franchises. Entergy Texas’s electric franchises expire during 2013-2058.

The business of System Energy is limited to wholesale power sales. It has no distribution franchises.

Property and Other Generation Resources

Generating Stations

The total capability of the generating stations owned and leased by the Utility operating companies and System Energy as of December 31, 2011, is indicated below:

	Owned and Leased Capability MW(1)
Company	Total	Gas/Oil	Nuclear	Coal	Hydro

Entergy Arkansas	4,774	1,668	1,823	1,209	74
Entergy Gulf States Louisiana	3,317	1,980	974	363	-
Entergy Louisiana	5,424	4,265	1,159	-	-
Entergy Mississippi	3,229	2,809	-	420	-
Entergy New Orleans	764	764	-	-	-
Entergy Texas	2,538	2,269	-	269	-
System Energy	1,071	-	1,071	-	-
Total	21,117	13,755	5,027	2,261	74

(1)	“Owned and Leased Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.

The Entergy System's load and capacity projections are reviewed periodically to assess the need and timing for additional generating capacity and interconnections. These reviews consider existing and projected demand, the availability and price of power, the location of new load, and the economy. Summer peak load in the Entergy System service territory has averaged 21,246 MW from 2002-2011. In the 2002 time period, the Entergy System's long-term capacity resources, allowing for an adequate reserve margin, were approximately 3,000 MW less than the total capacity required for peak period demands. In this time period the Entergy System met its capacity shortages almost entirely through short-term power purchases in the wholesale spot market. In the fall of 2002, the Entergy System began a program to add new resources to its existing generation portfolio and began a process of issuing requests for proposals (RFP) to procure supply-side resources from sources other than the spot market to meet the unique regional needs of the Utility operating companies. The Entergy System has adopted a long-term resource strategy that calls for the bulk of capacity needs to be met through long-term resources, whether owned or contracted. Entergy refers to this strategy as the "Portfolio Transformation Strategy". Over the past nine years, Portfolio Transformation has resulted in the addition of about 4,500 MW of new long-term resources. These figures do not include transactions currently pending as a result of the Summer 2009 RFP. When the Summer 2009 RFP transactions are included in

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the Entergy System portfolio of long-term resources and adjusting for unit deactivations of older generation, the Entergy System is approximately 500 MW short of its projected 2012 peak load plus reserve margin. This remaining need is expected to be met through a nuclear uprate at Grand Gulf and limited-term resources. The Entergy System will continue to access the spot power market to economically purchase energy in order to minimize customer cost. In addition, Entergy considers in its planning processes the notices from Entergy Arkansas and Entergy Mississippi regarding their future withdrawal from the System Agreement. Furthermore, as with other transmission systems, there are certain times during which congestion occurs on the Utility operating companies' transmission system that limits the ability of the Utility operating companies as well as other parties to fully utilize the generating resources that have been granted transmission service.

RFP Procurements

The RFPs issued by the Entergy System since the fall of 2002 have sought resources needed to meet near-term summer reliability requirements as well as longer-term resources through a broad range of wholesale power products, including limited-term (1 to 3 years) and long-term contractual products and asset acquisitions. Detailed evaluation processes have been developed to analyze submitted proposals, and, with the exception of the January 2008 RFP and the 2008 Western Region RFP, each RFP has been overseen by an independent monitor. The following table illustrates the results of the RFP process for resources acquired since the Fall 2002 RFP. The contracts below were primarily with non-affiliated suppliers, with the exception of contracts with EWO Marketing for the sale of 185 MW to 206 MW from the RS Cogen plant and contracts with Entergy Power for the sale of approximately 100 MW from the Independence plant.

RFP

Short-

term 3rd

party

Limited-term

affiliate

Limited-

term 3rd

party

Long-term

affiliate

Long-term

3rd party

Total

Fall 2002

185-206 MW (a)

231 MW

101-121 MW (b)

718 MW (d)

1,235-1,276 MW

January 2003 supplemental

222 MW

Spring 2003

381 MW

(c)

381 MW

Fall 2003

390 MW

Fall 2004

1,250 MW

2006 Long-Term

538 MW (e)

789 MW (f)

1,327 MW

Fall 2006

780 MW

January 2008 (g)

2008 Western Region

300 MW

Summer 2008 (h)

200 MW

January 2009 Western Region

150-300 MW

July 2009 Baseload

336 MW (i)

336 MW

Summer 2009 Long-Term (j)

551 MW

1555 MW

2106 MW

(a)	Includes a conditional option to increase the capacity up to the upper bound of the range.
(b)	The contracted capacity increased from 101 MW to 121 MW in 2010.
(c)	This table does not reflect (i) the River Bend 30% life-of-unit purchased power agreements totaling approximately 300 MW between Entergy Gulf States Louisiana and Entergy Louisiana (200 MW), and between Entergy Gulf States Louisiana and Entergy New Orleans (100 MW) related to Entergy Gulf States Louisiana's unregulated portion of the River Bend nuclear station, which portion was formerly owned by Cajun Electric Power Cooperative, Inc. or (ii) the Entergy Arkansas wholesale base load capacity life-of-unit purchased power agreements executed in 2003 totaling approximately 220 MW between Entergy Arkansas and Entergy Louisiana (110 MW) and between Entergy Arkansas and Entergy New Orleans (110 MW) related to the sale of a portion of Entergy Arkansas’s coal and nuclear base load resources (which were not included in retail rates); or (iii) 12-month agreements originally executed in 2005 and which are renewed annually between Entergy Arkansas and Entergy Gulf States Louisiana and Entergy Texas, and between Entergy Arkansas and Entergy Mississippi, relating to the sale of a portion of Entergy Arkansas’s coal and nuclear base load resources (which were not included in retail rates) to those companies. These resources were identified outside of the formal RFP process but were submitted as formal proposals in response to the Spring 2003 RFP, which confirmed the economic merits of these resources.
(d)	Entergy Louisiana's June 2005 purchase of the 718 MW, gas-fired Perryville plant, of which a total of 75% of the output is sold to Entergy Gulf States Louisiana and Entergy Texas.

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(e)	In 2011 the LPSC approved Entergy Louisiana’s cancellation of the Little Gypsy Unit 3 re-powering project selected from the 2006 Long-Term RFP.
(f)	Entergy Arkansas’s September 2008 purchase of the 789 MW, combined-cycle, gas-fired Ouachita Generating Facility, of which one-third of the output was sold to Entergy Gulf States Louisiana prior to the purchase of one-third of the facility by Entergy Gulf States Louisiana in November 2009.

(g)	At the direction of the LPSC, but with full reservation of all legal rights, Entergy Services issued the January 2008 RFP for Supply-Side Resources seeking fixed price unit contingent products. Although the LPSC request was directed to Entergy Gulf States Louisiana and Entergy Louisiana, Entergy Services issued the RFP on behalf of all of the Utility operating companies. No proposals were selected from this RFP.
(h)	In October 2008, in response to the U.S. financial crisis, Entergy Services on behalf of the Utility operating companies terminated all long-term procurement efforts, including the long-term portion of the Summer 2008 RFP.
(i)	Represents the self-supply alternative considered in the RFP, consisting of a cost-based purchase by Entergy Texas, Entergy Louisiana, and Entergy Mississippi of wholesale baseload capacity from Entergy Arkansas.
(j)	Includes the Ninemile self-build option, acquisitions from KGen of its Hinds and Hot Spring facilities and a long-term PPA with Calpine Carville. Contracts from the Summer 2009 Long-Term RFP have been executed but are still pending regulatory approvals.

Entergy Louisiana and Entergy New Orleans currently purchase, pursuant to ten-year purchased power agreements that expire in 2013, 121 MW of capacity and energy from Entergy Power sourced from Independence Steam Electric Station Unit 2. The transaction, which originated from the Fall 2002 RFP, included an option for Entergy Louisiana and Entergy New Orleans to acquire an ownership interest in the unit for a total price of $80 million, subject to various adjustments. In March 2008, Entergy Louisiana and Entergy New Orleans provided notice of their intent to exercise the option. Entergy Louisiana and Entergy New Orleans continue to evaluate the economics of proceeding with this option. Based upon changes in the long-term economics of the resource relative to current options, in August 2011, Entergy Louisiana made a filing with the LPSC seeking relief from the prior directive to exercise the option to purchase an ownership interest in the Independence unit. The LPSC staff filed testimony suggesting that the option should be exercised but noting that this is largely a policy decision for the LPSC.

In December 2010, on behalf of Entergy Gulf States Louisiana and Entergy Louisiana, Entergy Services issued the 2010 RFP for Long-Term Renewable Energy Resources seeking up to 233 MW of renewable generation resources to meet the requirements of an LPSC general order issued in December 2010. In November 2011, Entergy Services selected five resources for a total of 143 MW for the primary selection list and two additional proposals, representing 103 MW for the secondary selection list. The seven proposals collectively represent a mixture of as-available and baseload products, technologies, and geographic locations.

In June 2011, on behalf of Entergy Arkansas, Entergy Services issued the 2011 RFP for Transition Plan Resources. The RFP sought up to 750 MW of flexible generation resources through one or more purchased power agreements to address Entergy Arkansas’s requirements for its 2014-2016 time frame. Entergy Arkansas concluded its review and evaluation of the proposals submitted in response to the RFP in November 2011 and selected two proposals totaling approximately 795 MW for negotiation of definitive agreements.

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In December 2011, on behalf of Entergy Texas, Entergy Services issued the 2011 Western Region RFP for Long-Term Supply Side Resources. This RFP is seeking approximately 300 MW of baseload or flexible capacity, energy, and other electric products to meet the long-term reliability needs of the Western Region beginning in 2017. This RFP includes a self-build option at Entergy Texas’s Lewis Creek site.

Other Procurements From Third Parties

The above table does not include resource acquisitions made outside of the RFP process, including Entergy Mississippi's January 2006 acquisition of the 480 MW, combined-cycle, gas-fired Attala power plant; Entergy Gulf States Louisiana's March 2008 acquisition of the 322 MW, simple-cycle, gas-fired Calcasieu Generating Facility; and Entergy Louisiana’s April 2011 acquisition of the 580 MW, combined-cycle, gas-fired Acadia Energy Center Unit 2. The above table also does not reflect various limited- and long-term contracts that have been entered into in recent years by the Utility operating companies as a result of bilateral negotiations.

Interconnections

The Entergy System's generating units are interconnected by a transmission system operating at various voltages up to 500 kV. These generating units consist primarily of steam-electric production facilities and are centrally dispatched and operated. Entergy's Utility operating companies are interconnected with many neighboring utilities. In addition, the Utility operating companies are members of the SERC Reliability Corporation. The primary purpose of SERC is to ensure the reliability and adequacy of the electric bulk power supply in the southeast region of the United States. SERC is a member of the North American Electric Reliability Corporation.

Gas Property

As of December 31, 2011, Entergy New Orleans distributed and transported natural gas for distribution within Algiers and New Orleans, Louisiana, through 2,500 miles of gas pipeline. As of December 31, 2011, the gas properties of Entergy Gulf States Louisiana, which are located in and around Baton Rouge, Louisiana, were not material to Entergy Gulf States Louisiana's financial position.

Title

The Entergy System's generating stations are generally located on properties owned in fee simple. Most of the substations and transmission and distribution lines are constructed on private property or public rights-of-way pursuant to easements, servitudes, or appropriate franchises. Some substation properties are owned in fee simple. The Utility operating companies generally have the right of eminent domain, whereby they may perfect title to, or secure easements or servitudes on, private property for their utility operations.

Substantially all of the physical properties and assets owned by Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are subject to the liens of mortgages securing bonds issued by those companies. The Lewis Creek generating station is owned by GSG&T, Inc., a subsidiary of Entergy Texas, and is not subject to its mortgage lien. Lewis Creek is leased to and operated by Entergy Texas.

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Fuel Supply

The sources of generation and average fuel cost per kWh for the Utility operating companies and System Energy for the years 2009-2011 were:

	Natural Gas		Nuclear		Coal		Purchased Power
Year	% of Gen	Cents Per kWh	% of Gen	Cents Per kWh	% of Gen	Cents Per kWh	% of Gen	Cents Per kWh

2011	25	4.85	34	.81	13	2.31	28	4.59
2010	22	5.39	36	.78	13	2.00	29	5.28
2009	19	5.64	34	.66	12	2.04	35	5.29

Actual 2011 and projected 2012 sources of generation for the Utility operating companies and System Energy, including certain power purchases from affiliates under life of unit power purchase agreements, including the Unit Power Sales Agreement, are:

	Natural Gas		Nuclear		Coal		Purchased Power
	2011	2012	2011	2012	2011	2012	2011	2012

Entergy Arkansas (a)	3%	11%	57%	52%	24%	23%	16%	14%
Entergy Gulf States Louisiana	29%	31%	27%	19%	10%	11%	34%	39%
Entergy Louisiana	29%	27%	36%	40%	2%	2%	33%	31%
Entergy Mississippi	39%	40%	23%	23%	19%	20%	19%	17%
Entergy New Orleans	37%	34%	45%	45%	9%	9%	9%	12%
Entergy Texas	37%	19%	12%	16%	9%	11%	42%	54%
System Energy (b)	-	-	100%	100%	-	-	-	-
Utility (a)	25%	23%	34%	34%	13%	13%	28%	30%

(a)

Hydroelectric power provided less than 1% of Entergy Arkansas’s generation in 2011 and is expected to provide less than 1% of its generation in 2012.

(b)

Capacity and energy from System Energy’s interest in Grand Gulf is allocated as follows under the Unit Power Sales Agreement: Entergy Arkansas - 36%; Entergy Louisiana - 14%; Entergy Mississippi - 33%; and Entergy New Orleans - 17%. Pursuant to purchased power agreements, Entergy Arkansas is selling a portion of its owned capacity and energy from Grand Gulf to Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans.

Some of the Utility’s gas-fired plants are capable of also using fuel oil, if necessary. Although based on current economics the Utility does not expect fuel oil use in 2012, it is possible that various operational events including weather or pipeline maintenance may require the use of fuel oil.

Natural Gas

The Utility operating companies have long-term firm and short-term interruptible gas contracts for both supply and transportation. Long-term firm contracts for power plants comprise less than 25% of the Utility operating companies' total requirements. Short-term contracts and spot-market purchases satisfy additional gas requirements. Entergy Texas owns a gas storage facility that provides reliable and flexible natural gas service to certain generating stations.

Entergy Louisiana has a long-term natural gas supply contract, which expires January 1, 2013, in which Entergy Louisiana agreed to purchase natural gas in annual amounts equal to approximately one-third of its projected annual fuel requirements for certain generating units. Annual demand charges associated with this contract are estimated to be $6.6 million. Entergy Louisiana conducted an RFP to obtain a replacement supplier for this contract and is in negotiations with the prevailing bidder.

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Many factors, including wellhead deliverability, storage and pipeline capacity, and demand requirements of end users, influence the availability and price of natural gas supplies for power plants. Demand is tied to weather conditions as well as to the prices and availability of other energy sources. Pursuant to federal and state regulations, gas supplies to power plants may be interrupted during periods of shortage. To the extent natural gas supplies are disrupted or natural gas prices significantly increase, the Utility operating companies will use alternate fuels, such as oil, or rely to a larger extent on coal, nuclear generation, and purchased power.

Coal

Entergy Arkansas has committed to four one- to three-year contracts that will supply approximately 90% of the total coal supply needs in 2012. These contracts are staggered in term so that not all contracts have to be renewed the same year. The remaining 10% of total coal requirements will be satisfied by contracts with a term of less than one year. Based on greater Powder River Basin (PRB) coal deliveries and the high cost of foreign coal, no alternative coal consumption is expected at Entergy Arkansas during 2012. Entergy Arkansas has an existing long-term railroad transportation contract that will provide up to approximately 85% of Entergy Arkansas’s coal transportation requirements for 2012. An RFP for Entergy Arkansas’ open rail transportation position was issued in 2011 and a definitive agreement is expected by mid-2012.

Entergy Gulf States Louisiana has executed three one- to three-year contracts that will supply approximately 90% of Nelson Unit 6 coal needs in 2012. Additional PRB coal will be purchased through contracts with a term of less than one year to provide the remaining supply needs. For the same reasons as for Entergy Arkansas’s plants, no alternative coal consumption is expected at Nelson Unit 6 during 2012. Coal will be transported to Nelson via a new transportation agreement beginning January 1, 2012 that will provide approximately 90% to 100% of rail transportation requirements for 2012.

For the year 2011, coal transportation delivery to Entergy Arkansas operated coal-fired units met coal demand at the plants and it is expected that delivery times experienced in 2010 and 2011 will continue through 2012. In the fourth quarter 2011, Entergy Gulf States Louisiana experienced significant delivery shortfalls as the result of flood-related disruptions on the BNSF Railway. Inventory levels recovered by year end and improved transportation times are expected under the new transportation agreement beginning in 2012. Both Entergy Arkansas and Entergy Gulf States Louisiana control a sufficient number of railcars to satisfy the rail transportation requirement.

The operator of Big Cajun 2 - Unit 3, Louisiana Generating, LLC, has advised Entergy Gulf States Louisiana and Entergy Texas that it has adequate rail car and barge capacity to meet the volumes of low-sulfur PRB coal requested for 2012. Entergy Gulf States Louisiana’s and Entergy Texas’s coal nomination requests to Big Cajun 2 - Unit 3 are made on an annual basis.

Nuclear Fuel

The nuclear fuel cycle consists of the following:

·	mining and milling of uranium ore to produce a concentrate;

·	conversion of the concentrate to uranium hexafluoride gas;

·	enrichment of the uranium hexafluoride gas;

·	fabrication of nuclear fuel assemblies for use in fueling nuclear reactors; and

·	disposal of spent fuel.

The Registrant Subsidiaries that own nuclear plants (Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy), are responsible through a shared regulated uranium pool for contracts to acquire nuclear material to be used in fueling Entergy's Utility nuclear units. These companies own the materials and services in this shared regulated uranium pool on a pro rata fractional basis determined by the nuclear generation capability of each company. Any liabilities for obligations of the pooled contracts are on a several but not joint basis. The shared regulated uranium pool maintains inventories of nuclear materials during the various stages of

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processing. The Registrant Subsidiaries purchase enriched uranium hexafluoride for their nuclear plant reload requirements at the average inventory cost from the shared regulated uranium pool. Entergy Operations Inc. contracts separately for the fabrication of nuclear fuel as agent on behalf of each of the Registrant Subsidiaries that owns a nuclear plant. All contracts for the disposal of spent nuclear fuel are between the Department of Energy (DOE) and the owner of a nuclear power plant.

Based upon currently planned fuel cycles, the nuclear units in both the Utility and Entergy Wholesale Commodities segments have a diversified portfolio of contracts and inventory that provides substantially adequate nuclear fuel materials and conversion and enrichment services at what Entergy believes are reasonably predictable or fixed prices through most of 2012. Entergy’s ability to purchase nuclear fuel at reasonably predictable prices, however, depends upon the performance reliability of uranium miners. There are a number of possible alternate suppliers that may be accessed to mitigate any supplier performance failure, including potentially drawing upon Entergy’s inventory intended for later generation periods depending upon its risk management strategy at that time, although the pricing of any alternate uranium supply from the market will be dependent upon the market for uranium supply at that time. In addition, some nuclear fuel contracts are on a non-fixed price basis subject to prevailing prices at the time of delivery.

The effects of market price changes may be reduced and deferred by risk management strategies, such as negotiation of floor and ceiling amounts for long-term contracts, buying for inventory or entering into forward physical contracts at fixed prices when Entergy believes it is appropriate and useful. Entergy buys uranium from a diversified mix of sellers located in a diversified mix of countries, and from time to time purchases from nearly all qualified reliable major market participants worldwide that sell into the U.S.

Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy each have made arrangements to lease nuclear fuel and related equipment and services. The lessors, which are consolidated in the financial statements of Entergy and the applicable Registrant Subsidiary, finance the acquisition and ownership of nuclear fuel through credit agreements and the issuance of notes. These arrangements are subject to periodic renewal.

Natural Gas Purchased for Resale

Entergy New Orleans has several suppliers of natural gas. Its system is interconnected with three interstate and three intrastate pipelines. Entergy New Orleans has a "no-notice" service gas purchase contract with Atmos Energy which guarantees Entergy New Orleans gas delivery at specific delivery points and at any volume within the minimum and maximum set forth in the contract amounts. The Atmos Energy gas supply is transported to Entergy New Orleans pursuant to a transportation service agreement with Gulf South Pipeline Co. This service is subject to FERC-approved rates. Entergy New Orleans also makes interruptible spot market purchases. In recent years, natural gas deliveries to Entergy New Orleans have been subject primarily to weather-related curtailments.

As a result of the implementation of FERC-mandated interstate pipeline restructuring in 1993, curtailments of interstate gas supply could occur if Entergy New Orleans's suppliers failed to perform their obligations to deliver gas under their supply agreements. Gulf South Pipeline Co. could curtail transportation capacity only in the event of pipeline system constraints.

Entergy Gulf States Louisiana purchases natural gas for resale under a firm contract from Enbridge Marketing (U.S.) Inc. The gas is delivered through a combination of intrastate and interstate pipelines.

Federal Regulation of the Utility

State or local regulatory authorities, as described above, regulate the retail rates of the Utility operating companies. The FERC regulates wholesale rates (including intrasystem sales pursuant to the System Agreement) and interstate transmission of electricity, as well as rates for System Energy’s sales of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans pursuant to the Unit Power Sales Agreement.

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System Agreement (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas)

The Utility operating companies historically have engaged in the coordinated planning, construction, and operation of generating and bulk transmission facilities under the terms of the System Agreement, which is a rate schedule that has been approved by the FERC. Under the terms of the System Agreement, generating capacity and other power resources are jointly operated by the Utility operating companies. The System Agreement provides, among other things, that parties having generating reserves greater than their allocated share of reserves (long companies) shall receive payments from those parties having generating reserves that are less than their allocated share of reserves (short companies). Such payments are at amounts sufficient to cover certain of the long companies’ costs for intermediate and peaking oil/gas-fired generation, including operating expenses, fixed charges on debt, dividend requirements on preferred equity, and a fair rate of return on common equity investment. Under the System Agreement, the rates used to compensate long companies are based on costs associated with the long companies’ steam electric generating units fueled by oil or gas and having an annual average heat rate above 10,000 Btu/kWh. In addition, for all energy exchanged among the Utility operating companies under the System Agreement, the companies purchasing exchange energy are required to pay the cost of fuel consumed in generating such energy plus a charge to cover other associated costs.

Citing its concerns that the benefits of its continued participation in the current form of the System Agreement have been seriously eroded, in December 2005, Entergy Arkansas submitted its notice that it will terminate its participation in the current System Agreement effective ninety-six (96) months from the date of the notice or such earlier date as authorized by the FERC. In November 2007, pursuant to the provisions of the System Agreement, Entergy Mississippi provided its written notice to terminate its participation in the System Agreement effective ninety-six (96) months from the date of the notice or such earlier date as authorized by the FERC. In light of the notices of Entergy Arkansas and Entergy Mississippi to terminate participation in the current System Agreement, in January 2008 the LPSC unanimously voted to direct the LPSC Staff to begin evaluating the potential for a new agreement. Likewise, the New Orleans City Council opened a docket to gather information on progress towards a successor agreement.

In November 2009 the FERC accepted the notices of cancellation and determined that Entergy Arkansas and Entergy Mississippi are permitted to withdraw from the System Agreement following the 96 month notice period without payment of a fee or being required to otherwise compensate the remaining Utility operating companies as a result of withdrawal. In February 2011 the FERC denied the LPSC’s and the City Council’s rehearing requests. The LPSC has appealed the FERC’s decision to the U.S. Court of Appeals for the District of Columbia, and oral argument was held in the case in January 2012.

See “System Agreement” in Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for discussion of the proceedings at the FERC involving the System Agreement and other related proceedings.

Transmission

See the “Plan to Spin Off the Utility’s Transmission Business” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis.

See “Independent Coordinator of Transmission” in the “Rate, Cost-recovery, and Other Regulation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis.

System Energy and Related Agreements

System Energy recovers costs related to its interest in Grand Gulf through rates charged to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans for capacity and energy under the Unit Power Sales Agreement (described below). In December 1995, System Energy commenced a rate proceeding at the FERC. In July 2001, the rate proceeding became final, with the FERC approving a prospective 10.94% return on equity. The

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FERC’s decision also affected other aspects of System Energy’s charges to the Utility operating companies that it supplies with power. In 1998, the FERC approved requests by Entergy Arkansas and Entergy Mississippi to accelerate a portion of their Grand Gulf purchased power obligations. Entergy Arkansas’s and Entergy Mississippi’s acceleration of Grand Gulf purchased power obligations ceased effective July 2001 and July 2003, respectively, as approved by the FERC.

Unit Power Sales Agreement

The Unit Power Sales Agreement allocates capacity, energy, and the related costs from System Energy’s ownership and leasehold interests in Grand Gulf to Entergy Arkansas (36%), Entergy Louisiana (14%), Entergy Mississippi (33%), and Entergy New Orleans (17%). Each of these companies is obligated to make payments to System Energy for its entitlement of capacity and energy on a full cost-of-service basis regardless of the quantity of energy delivered. Payments under the Unit Power Sales Agreement are System Energy’s only source of operating revenue. The financial condition of System Energy depends upon the continued commercial operation of Grand Gulf and the receipt of such payments. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans generally recover payments made under the Unit Power Sales Agreement through rates charged to their customers.

In the case of Entergy Arkansas and Entergy Louisiana, payments are also recovered through sales of electricity from their respective retained shares of Grand Gulf. Under a settlement agreement entered into with the APSC in 1985 and amended in 1988, Entergy Arkansas retains 22% of its 36% share of Grand Gulf-related costs and recovers the remaining 78% of its share in rates. In the event that Entergy Arkansas is not able to sell its retained share to third parties, it may sell such energy to its retail customers at a price equal to its avoided cost, which is currently less than Entergy Arkansas’s cost from its retained share. Entergy Arkansas has life-of-resources purchased power agreements with Entergy Louisiana and Entergy New Orleans that sell a portion of the output of Entergy Arkansas’s retained share of Grand Gulf to those companies. In a series of LPSC orders, court decisions, and agreements from late 1985 to mid-1988, Entergy Louisiana was granted rate relief with respect to costs associated with Entergy Louisiana’s share of capacity and energy from Grand Gulf, subject to certain terms and conditions. Entergy Louisiana retains and does not recover from retail ratepayers 18% of its 14% share of the costs of Grand Gulf capacity and energy and recovers the remaining 82% of its share in rates. Entergy Louisiana is allowed to recover through the fuel adjustment clause at 4.6 cents per kWh for the energy related to its retained portion of these costs. Alternatively, Entergy Louisiana may sell such energy to non-affiliated parties at prices above the fuel adjustment clause recovery amount, subject to the LPSC’s approval.

Availability Agreement

The Availability Agreement among System Energy and Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans was entered into in 1974 in connection with the financing by System Energy of Grand Gulf. The Availability Agreement provides that System Energy make available to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans all capacity and energy available from System Energy’s share of Grand Gulf.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans also agreed severally to pay System Energy monthly for the right to receive capacity and energy from Grand Gulf in amounts that (when added to any amounts received by System Energy under the Unit Power Sales Agreement) would at least equal System Energy’s total operating expenses for Grand Gulf (including depreciation at a specified rate and expenses incurred in a permanent shutdown of Grand Gulf) and interest charges. The September 1989 write-off of System Energy’s investment in Grand Gulf 2, amounting to approximately $900 million, is being amortized for Availability Agreement purposes over 27 years.

The allocation percentages under the Availability Agreement are fixed as follows: Entergy Arkansas - 17.1%; Entergy Louisiana - 26.9%; Entergy Mississippi - 31.3%; and Entergy New Orleans - 24.7%. The allocation percentages under the Availability Agreement would remain in effect and would govern payments made under such agreement in the event of a shortfall of funds available to System Energy from other sources, including payments under the Unit Power Sales Agreement.

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System Energy has assigned its rights to payments and advances from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans under the Availability Agreement as security for its first mortgage bonds and reimbursement obligations to certain banks providing letters of credit in connection with the equity funding of the sale and leaseback transactions described in Note 10 to the financial statements under “Sale and Leaseback Transactions - Grand Gulf Lease Obligations.” In these assignments, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans further agreed that, in the event they were prohibited by governmental action from making payments under the Availability Agreement (for example, if the FERC reduced or disallowed such payments as constituting excessive rates), they would then make subordinated advances to System Energy in the same amounts and at the same times as the prohibited payments. System Energy would not be allowed to repay these subordinated advances so long as it remained in default under the related indebtedness or in other similar circumstances.

Each of the assignment agreements relating to the Availability Agreement provides that Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans will make payments directly to System Energy. However, if there is an event of default, those payments must be made directly to the holders of indebtedness that are the beneficiaries of such assignment agreements. The payments must be made pro rata according to the amount of the respective obligations secured.

The obligations of Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans to make payments under the Availability Agreement are subject to the receipt and continued effectiveness of all necessary regulatory approvals. Sales of capacity and energy under the Availability Agreement would require that the Availability Agreement be submitted to the FERC for approval with respect to the terms of such sale. No such filing with the FERC has been made because sales of capacity and energy from Grand Gulf are being made pursuant to the Unit Power Sales Agreement. If, for any reason, sales of capacity and energy are made in the future pursuant to the Availability Agreement, the jurisdictional portions of the Availability Agreement would be submitted to the FERC for approval.

Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement to System Energy have exceeded the amounts payable under the Availability Agreement. Therefore, no payments under the Availability Agreement have ever been required. If Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments because their Availability Agreement obligations exceed their Unit Power Sales Agreement obligations.

The Availability Agreement may be terminated, amended, or modified by mutual agreement of the parties thereto, without further consent of any assignees or other creditors.

Capital Funds Agreement

System Energy and Entergy Corporation have entered into the Capital Funds Agreement, whereby Entergy Corporation has agreed to supply System Energy with sufficient capital to (i) maintain System Energy’s equity capital at an amount equal to a minimum of 35% of its total capitalization (excluding short-term debt) and (ii) permit the continued commercial operation of Grand Gulf and pay in full all indebtedness for borrowed money of System Energy when due.

Entergy Corporation has entered into various supplements to the Capital Funds Agreement. System Energy has assigned its rights under such supplements as security for its first mortgage bonds and for reimbursement obligations to certain banks providing letters of credit in connection with the equity funding of the sale and leaseback transactions described in Note 10 to the financial statements under “Sale and Leaseback Transactions - Grand Gulf Lease Obligations.” Each such supplement provides that permitted indebtedness for borrowed money incurred by System Energy in connection with the financing of Grand Gulf may be secured by System Energy’s rights under

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the Capital Funds Agreement on a pro rata basis (except for the Specific Payments, as defined below). In addition, in the supplements to the Capital Funds Agreement relating to the specific indebtedness being secured, Entergy Corporation has agreed to make cash capital contributions directly to System Energy sufficient to enable System Energy to make payments when due on such indebtedness (Specific Payments). However, if there is an event of default, Entergy Corporation must make those payments directly to the holders of indebtedness benefiting from the supplemental agreements. The payments (other than the Specific Payments) must be made pro rata according to the amount of the respective obligations benefiting from the supplemental agreements.

The Capital Funds Agreement may be terminated, amended, or modified by mutual agreement of the parties thereto, upon obtaining the consent, if required, of those holders of System Energy’s indebtedness then outstanding who have received the assignments of the Capital Funds Agreement.

Service Companies

Entergy Services, a corporation wholly-owned by Entergy Corporation, provides management, administrative, accounting, legal, engineering, and other services primarily to the Utility operating companies. Entergy Operations is also wholly-owned by Entergy Corporation and provides nuclear management, operations and maintenance services under contract for ANO, River Bend, Waterford 3, and Grand Gulf, subject to the owner oversight of Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy, respectively. Entergy Services and Entergy Operations provide their services to the Utility operating companies and System Energy on an “at cost” basis, pursuant to cost allocation methodologies for these service agreements that were approved by the FERC.

Jurisdictional Separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas

Effective December 31, 2007, Entergy Gulf States, Inc. completed a jurisdictional separation into two vertically integrated utility companies, one operating under the sole retail jurisdiction of the PUCT, Entergy Texas, and the other operating under the sole retail jurisdiction of the LPSC, Entergy Gulf States Louisiana. Management believes that the jurisdictional separation better aligns Entergy Gulf States, Inc.’s Louisiana and Texas operations to serve customers in those states and to operate consistent with state-specific regulatory requirements as the utility regulatory environments in those jurisdictions evolve. The jurisdictional separation provides for regulation of each separated company by a single retail regulator, which should reduce regulatory complexity.

Entergy Texas now owns all Entergy Gulf States, Inc. distribution and transmission assets located in Texas, the gas-fired generating plants located in Texas, undivided 42.5% ownership shares of Entergy Gulf States, Inc.’s 70% ownership interest in Nelson 6 and 42% ownership interest in Big Cajun 2, Unit 3, which are coal-fired generating plants located in Louisiana, and other assets and contract rights to the extent related to utility operations in Texas. Entergy Gulf States Louisiana now owns all of the remaining assets that were owned by Entergy Gulf States, Inc. On a book value basis, approximately 58.1% of the Entergy Gulf States, Inc. assets were allocated to Entergy Gulf States Louisiana and approximately 41.9% were allocated to Entergy Texas.

Entergy Gulf States Louisiana remained primarily liable for all of the long-term debt issued by Entergy Gulf States, Inc. that was outstanding on December 31, 2007. Under a debt assumption agreement with Entergy Gulf States Louisiana, Entergy Texas assumed its pro rata share of this long-term debt, which was $1.079 billion, or approximately 46%, which had been entirely paid-off as of December 31, 2010. The pro rata share of the long-term debt assumed by Entergy Texas was determined by first determining the net assets for each company on a book value basis, and then calculating a debt assumption ratio that resulted in the common equity ratios for each company being approximately the same as the Entergy Gulf States, Inc. common equity ratio immediately prior to the jurisdictional separation.

Entergy Texas purchases from Entergy Gulf States Louisiana pursuant to a life-of-unit purchased power agreement (PPA) a 42.5% share of capacity and energy from the 70% of River Bend subject to retail regulation. Entergy Texas was allocated a share of River Bend’s nuclear and environmental liabilities that is identical to the share of the plant’s output purchased by Entergy Texas under the PPA. Entergy Gulf States Louisiana purchases a 57.5% share

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of capacity and energy from the gas-fired generating plants owned by Entergy Texas, and Entergy Texas purchases a 42.5% share of capacity and energy from the gas-fired generating plants owned by Entergy Gulf States Louisiana. The PPAs associated with the gas-fired generating plants will terminate when the unit(s) is/are no longer dispatched by the Entergy System. The dispatch and operation of the generating plants will not change as a result of the jurisdictional separation.

The jurisdictional separation occurred through completion of the following steps:

·	Through a Texas statutory merger-by-division, Entergy Gulf States, Inc. was renamed as Entergy Gulf States Louisiana, Inc., a Texas corporation, and the new Texas business corporation Entergy Texas, Inc. was formed.

·	Entergy Gulf States, Inc. allocated the assets described above to Entergy Texas, and all of the capital stock of Entergy Texas was issued directly to Entergy Gulf States, Inc.’s parent company, Entergy Corporation.

·	Entergy Corporation formed EGS Holdings, Inc., a Texas corporation, and contributed all of the common stock of Entergy Gulf States Louisiana, Inc. to EGS Holdings, Inc.

·	EGS Holdings, Inc. formed the Louisiana limited liability company Entergy Gulf States Louisiana, L.L.C. and then owned all of the issued and outstanding membership interests of Entergy Gulf States Louisiana, L.L.C.

·	Entergy Gulf States Louisiana, Inc. then merged into Entergy Gulf States Louisiana, L.L.C., with Entergy Gulf States Louisiana, L.L.C. being the surviving entity.

·	Entergy Corporation now owns EGS Holdings, Inc. and Entergy Texas in their entirety, and EGS Holdings, Inc. now owns Entergy Gulf States Louisiana’s common membership interests in their entirety.

Earnings Ratios of Registrant Subsidiaries

The Registrant Subsidiaries’ ratios of earnings to fixed charges and ratios of earnings to combined fixed charges and preferred dividends or distributions pursuant to Item 503 of SEC Regulation S-K are as follows:

	Ratios of Earnings to Fixed Charges Years Ended December 31,
	2011	2010	2009	2008	2007

Entergy Arkansas	4.31	3.91	2.39	2.33	3.19
Entergy Gulf States Louisiana	4.36	3.58	2.99	2.44	2.84
Entergy Louisiana	1.86	3.41	3.52	3.14	3.44
Entergy Mississippi	3.55	3.35	3.31	2.92	3.22
Entergy New Orleans	5.37	4.43	3.61	3.71	2.74
Entergy Texas	2.34	2.10	1.92	2.04	2.07
System Energy	3.85	3.64	3.73	3.29	3.95

	Ratios of Earnings to Combined Fixed Charges and Preferred Dividends or Distributions Years Ended December 31,
	2011	2010	2009	2008	2007

Entergy Arkansas	3.83	3.60	2.09	1.95	2.88
Entergy Gulf States Louisiana	4.30	3.54	2.95	2.42	2.73
Entergy Louisiana	1.70	3.19	3.27	2.87	3.08
Entergy Mississippi	3.27	3.16	3.06	2.67	2.97
Entergy New Orleans	4.74	4.08	3.33	3.45	2.54

The Registrant Subsidiaries accrue interest expense related to unrecognized tax benefits in income tax expense and do not include it in fixed charges.

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Entergy Wholesale Commodities

During 2010 Entergy integrated its non-utility nuclear and its non-nuclear wholesale assets businesses into a new organization called Entergy Wholesale Commodities.

Entergy Wholesale Commodities includes the ownership and operation of six nuclear power plants, five of which are located in the Northeast United States, with the sixth located in Michigan, and is primarily focused on selling electric power produced by those plants to wholesale customers. Entergy Wholesale Commodities’ revenues are primarily derived from sales of energy and generation capacity from these plants. Entergy Wholesale Commodities also provides operations and management services, including decommissioning services, to nuclear power plants owned by other utilities in the United States.

Entergy Wholesale Commodities also includes the ownership of, or participation in joint ventures that own, non-nuclear power plants and the sale to wholesale customers of the electric power produced by these plants.

Property

Nuclear Generating Stations

Entergy Wholesale Commodities includes the ownership of the following nuclear power plants:

Power Plant

Market

Service

Year

Acquired

Location

Capacity-

Reactor Type

License

Expiration

Date

Pilgrim

IS0-NE

1972

July 1999

Plymouth, MA

688 MW - Boiling Water

2012

FitzPatrick

NYISO

1975

Nov. 2000

Oswego, NY

838 MW - Boiling Water

2034

Indian Point 3

NYISO

1976

Nov. 2000

Buchanan, NY

1,041 MW - Pressurized Water

2015

Indian Point 2

NYISO

1974

Sept. 2001

Buchanan, NY

1,028 MW - Pressurized Water

2013

Vermont Yankee

IS0-NE

1972

July 2002

Vernon, VT

605 MW - Boiling Water

2032

Palisades

MISO

1971

Apr. 2007

South Haven, MI

811 MW - Pressurized Water

2031

Entergy Wholesale Commodities also includes the ownership of two non-operating nuclear facilities, Big Rock Point in Michigan and Indian Point 1 in New York that were acquired when Entergy purchased the Palisades and Indian Point 2 nuclear plants, respectively. These facilities are in various stages of the decommissioning process.

The NRC operating license for Vermont Yankee was to expire in March 2012. In March 2011 the NRC renewed Vermont Yankee’s operating license for an additional 20 years, as a result of which the license now expires in 2032. For additional discussion regarding the continued operation of the Vermont Yankee plant, see “Impairment of Long-Lived Assets” in Note 1 to the financial statements.

The operating licenses for Pilgrim, Indian Point 2, and Indian Point 3 expire between 2012 and 2015. Under federal law, nuclear power plants may continue to operate beyond their license expiration dates while their renewal applications are pending NRC approval. Various parties have expressed opposition to renewal of the licenses. With respect to the Pilgrim license renewal, the Atomic Safety and Licensing Board (ASLB) of the NRC, after issuing an order denying a new hearing request, terminated its proceeding on Pilgrim’s license renewal application. With the ASLB process concluded the proceeding, including appeals of certain ASLB decisions, is now before the NRC.

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disposition of an admitted contention challenging the adequacy of a section of Indian Point’s environmental analysis as incorporated in the FSEIS (discussed below). That section provided cost estimates for Severe Accident Mitigation Alternatives (SAMAs), which are hardware and procedural changes that could be implemented to mitigate estimated impacts of off-site radiological releases in case of a hypothesized severe accident. In addition to finding that the SAMA cost analysis was insufficient, the ASLB directed the NRC staff to explain why cost-beneficial SAMAs should not be required to be implemented. Entergy appealed the ASLB’s decision to the NRC and the NRC staff supported Entergy’s appeal, while the State of New York opposed it. In December 2011 the NRC denied Entergy’s appeal as premature, stating that the appeal could be renewed at the conclusion of the ASLB proceedings.

Non-nuclear Generating Stations

Entergy Wholesale Commodities includes the ownership, or interests in joint ventures that own, the following non-nuclear power plants:

Plant	Location	Ownership	Net Owned Capacity(1)	Type

Rhode Island State Energy Center; 583 MW	Johnston, RI	100%	583 MW	Gas
Ritchie Unit 2; 544 MW	Helena, AR	100%	544 MW	Gas/Oil
Independence Unit 2; 842 MW (2)	Newark, AR	14%	121 MW(3)	Coal
Top of Iowa; 80 MW (4)	Worth County, IA	50%	40 MW	Wind
White Deer; 80 MW (4)	Amarillo, TX	50%	40 MW	Wind
RS Cogen; 425 MW (4)	Lake Charles, LA	50%	213 MW	Gas/Steam
Nelson 6; 550 MW	Westlake, LA	11%	60 MW(3)	Gas

(1)

“Net Owned Capacity” refers to the nameplate rating on the generating unit.

(2)

Entergy Louisiana and Entergy New Orleans currently purchase 101 MW of capacity and energy from Independence Unit 2. The transaction included an option for Entergy Louisiana and Entergy New Orleans to acquire an ownership interest in the unit for a total price of $80 million, subject to various adjustments. In March 2008, Entergy Louisiana and Entergy New Orleans provided notice of their intent to exercise the option. Entergy Louisiana and Entergy New Orleans continue to evaluate the economics of proceeding with this option. Based upon changes in the long-term economics of the resource relative to current options, in August 2011, Entergy Louisiana made a filing with the LPSC seeking relief from the prior directive to exercise the option to purchase an ownership interest in the Independence unit. The LPSC staff filed testimony suggesting that the option should be exercised but noting that this is largely a policy decision for the LPSC.

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(3)	The owned MW capacity is the portion of the plant capacity owned by Entergy Wholesale Commodities. For a complete listing of Entergy’s jointly-owned generating stations, refer to “Jointly-Owned Generating Stations” in Note 1 to the financial statements.
(4)	Indirectly owned through interests in unconsolidated joint ventures.

In the fourth quarter 2010, Entergy sold its 61 percent share of the Harrison County 550 MW combined cycle gas-fired power plant.

Independent System Operators

The Pilgrim and Vermont Yankee and Rhode Island plants fall under the authority of the Independent System Operator (ISO) New England and the FitzPatrick and Indian Point plants fall under the authority of the New York Independent System Operator (NYISO). The Palisades plant falls under the authority of the MISO. The primary purpose of ISO New England, NYISO, and MISO is to direct the operations of the major generation and transmission facilities in their respective regions; ensure grid reliability; administer and monitor wholesale electricity markets; and plan for their respective region’s energy needs.

Energy and Capacity Sales

As a wholesale generator, Entergy Wholesale Commodities core business is selling energy, measured in MWh, to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and sells energy in the day ahead or spot markets. In addition to selling the energy produced by its plants, Entergy Wholesale Commodities sells unforced capacity, which allows load-serving entities to meet specified reserve and related requirements placed on them by the ISOs in their respective areas. Entergy Wholesale Commodities’ forward fixed price power contracts consist of contracts to sell energy only, contracts to sell capacity only, and bundled contracts in which it sells both capacity and energy. While the terminology and payment mechanics vary in these contracts, each of these types of contracts requires Entergy Wholesale Commodities to deliver MWh of energy, make capacity available, or both. See “Commodity Price Risk - Power Generation” in Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for additional information regarding these contracts.

In addition to the contracts discussed in “Commodity Price Risk - Power Generation,” Entergy’s purchase of the Vermont Yankee plant included a value sharing agreement providing for payments to the seller in the event that the plant operates beyond March 2012 pursuant to a renewed NRC operating license. Under the value sharing agreement, to the extent that the average annual price of the energy sales from the plant exceeds the specified strike price, initially $61/MWh and then adjusted annually based on three indices, Vermont Yankee will pay 50% of the amount exceeding the strike prices to the seller. These payments, if required, will be recorded as adjustments to the purchase price of the plants. The value sharing would begin in 2012 and extend into 2022.

As part of the purchase of the Palisades plant, Entergy executed a 15-year PPA with the seller, Consumers Energy, for 100% of the plant’s output, excluding any future uprates. Under the purchased power agreement, Consumers Energy will receive the value of any new environmental credits for the first ten years of the agreement. Palisades and Consumers Energy will share on a 50/50 basis the value of any new environmental credits for years 11 through 15 of the agreement. The environmental credits are defined as benefits from a change in law that causes capability of the plant as of the purchase date to become a tradable attribute (e.g., emission credit, renewable energy credit, environmental credit, “green” credit, etc.) or otherwise to have a market value.

Customers

Entergy Wholesale Commodities’ customers for the sale of both energy and capacity from its nuclear plants include retail power providers, utilities, electric power co-operatives, power trading organizations and other power generation companies. These customers include Consolidated Edison, NYPA, and Consumers Energy, companies from which Entergy purchased plants, and ISO New England and NYISO. Substantially all of the counterparties or their guarantors for the planned energy output under contract for Entergy Wholesale Commodities nuclear plants have public investment grade credit ratings or are load-serving entities without public credit ratings.

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Competition

The ISO New England and NYISO markets are highly competitive. Entergy Wholesale Commodities has numerous competitors in New England and New York, including generation companies affiliated with regulated utilities, other independent power producers, municipal and co-operative generators, owners of co-generation plants and wholesale power marketers. Entergy Wholesale Commodities is an independent power producer, which means it generates power for sale to third parties at day ahead or spot market prices to the extent that the power is not sold under a fixed price contract. Municipal and co-operative generators also generate power but use most of it to deliver power to their municipal or co-operative power customers. Owners of co-generation plants produce power primarily for their own consumption. Wholesale power marketers do not own generation; rather they buy power from generators or other market participants and resell it to retail providers or other market participants. Competition in the New England and New York power markets is affected by, among other factors, the amount of generation and transmission capacity in these markets. MISO does not have a formal, centralized forward capacity market, but load serving entities do transact capacity through bilateral contracts. Palisades’s current output is contracted to Consumers Energy through 2022 and, therefore, Entergy Wholesale Commodities does not expect to be materially affected by competition in the MISO market in the near term.

Seasonality

Entergy Wholesale Commodities’ revenues and operating income are subject to fluctuations during the year due to seasonal factors, weather conditions, and contract pricing. Refueling outages are generally scheduled for the spring and the fall, and cause volumetric decreases during those seasons. When outdoor and cooling water temperatures are lower, generally during colder months, Entergy Wholesale Commodities’ nuclear power plants operate more efficiently, and consequently, generate more electricity. Many of Entergy Wholesale Commodities’ contracts provide for shaped pricing over the course of the year. As a result of these factors, Entergy Wholesale Commodities’ revenues are typically higher in the first and third quarters than in the second and fourth quarters.

Fuel Supply

Nuclear Fuel

See “Fuel Supply, Nuclear Fuel” in the Utility portion of Part I, Item 1 for a discussion of the nuclear fuel cycle and markets. Entergy Nuclear Fuels Company, a wholly-owned subsidiary, is responsible for contracts to acquire nuclear materials, except for fuel fabrication, for Entergy Wholesale Commodities’ nuclear power plants, while Entergy Nuclear Operations, Inc. acts as the agent for the purchase of nuclear fuel assembly fabrication services. All contracts for the disposal of spent nuclear fuel are between the DOE and each of the nuclear power plants.

Other Business Activities

Entergy Nuclear Power Marketing, LLC (ENPM) was formed in 2005 to centralize the power marketing function for Entergy Wholesale Commodities nuclear plants. Upon its formation, ENPM entered into long-term power purchase agreements with the Entergy Wholesale Commodities subsidiaries that own nuclear power plants (generating subsidiaries). As part of a series of agreements, ENPM agreed to assume and/or otherwise service the existing power purchase agreements that were in effect between the generating subsidiaries and their customers. ENPM functions include origination of new energy and capacity transactions, generation scheduling, contract management (including billing and settlements), and market and credit risk mitigation.

Entergy Nuclear, Inc. pursues service agreements with other nuclear power plant owners who seek the advantages of Entergy’s scale and expertise but do not necessarily want to sell their assets. Services provided by either Entergy Nuclear, Inc. or other Entergy Wholesale Commodities subsidiaries include engineering, operations and maintenance, fuel procurement, management and supervision, technical support and training, administrative support, and other managerial or technical services required to operate, maintain, and decommission nuclear electric power facilities. Entergy Nuclear, Inc. provided decommissioning services for the Maine Yankee nuclear power plant and continues to pursue opportunities for Entergy Wholesale Commodities with other nuclear plant owners through operating agreements or innovative arrangements such as structured leases.

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Entergy Nuclear, Inc. also offers operating license renewal and life extension services to nuclear power plant owners. TLG Services, a subsidiary of Entergy Nuclear Inc., offers decommissioning, engineering, and related services to nuclear power plant owners. In April 2009, Entergy announced that it will team with energy firm ENERCON to offer nuclear development services ranging from plant relicensing to full-service, new plant deployment. ENERCON has experience in engineering, environmental, technical and management services.

In September 2003, Entergy agreed to provide plant operation support services for the 800 MW Cooper Nuclear Station located near Brownville, Nebraska. The original contract was to expire in 2014 corresponding to the original operating license life of the plant. In 2006, an Entergy subsidiary signed an agreement to provide license renewal services for the Cooper Nuclear Station. The Cooper Nuclear Station received its license renewal from the NRC on November 29, 2010. Entergy continues to provide implementation services for the renewed license. In 2010 an Entergy subsidiary signed an agreement to extend the management support services to Cooper Nuclear Station by 15 years, through January 2029.

Entergy-Koch

Entergy-Koch is a joint venture owned 50% each by subsidiaries of Entergy and Koch Industries, Inc, and is no longer an operating entity. Entergy-Koch began operations on February 1, 2001. Entergy contributed most of the assets and trading contracts of its power marketing and trading business and $414 million cash to the venture and Koch contributed its approximately 8,000-mile Koch Gateway Pipeline (renamed Gulf South Pipeline), gas storage facilities, and Koch Energy Trading, which marketed and traded electricity, gas, weather derivatives, and other energy-related commodities and services. In the fourth quarter 2004, Entergy-Koch sold its energy trading and pipeline businesses to third parties. Entergy received $862 million of cash distributions in 2004 from Entergy-Koch after the business sales. Due to the November 2006 expiration of contingencies on the sale of Entergy-Koch’s trading business, and the corresponding release to Entergy-Koch of sales proceeds held in escrow, Entergy received additional cash distributions of approximately $163 million during the fourth quarter of 2006 and recorded a gain of approximately $55 million (net-of-tax). In December 2009, Entergy reorganized its investment in Entergy-Koch, received a $25.6 million cash distribution, and received a distribution of certain software owned by the joint venture.

Regulation of Entergy’s Business

Federal Power Act

The Federal Power Act provides the FERC the authority to regulate:

·	the transmission and wholesale sale of electric energy in interstate commerce;

·	sales or acquisition of certain assets;

·	securities issuances;

·	the licensing of certain hydroelectric projects;

·	certain other activities, including accounting policies and practices of electric and gas utilities; and

·	changes in control of FERC jurisdictional entities or rate schedules.

The Federal Power Act gives the FERC jurisdiction over the rates charged by System Energy for Grand Gulf capacity and energy provided to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans and over some of the rates charged by Entergy Arkansas and Entergy Gulf States Louisiana. The FERC also regulates the provisions of the System Agreement, including the rates, and the provision of transmission service to wholesale market participants.

Entergy Arkansas holds a FERC license that expires in 2053 for two hydroelectric projects totaling 70 MW of capacity.

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State Regulation

Utility

Entergy Arkansas is subject to regulation by the APSC, which includes the authority to:

·	oversee utility service;

·	set retail rates;

·	determine reasonable and adequate service;

·	control leasing;

·	control the acquisition or sale of any public utility plant or property constituting an operating unit or system;

·	set rates of depreciation;

·	issue certificates of convenience and necessity and certificates of environmental compatibility and public need; and

·	regulate the issuance and sale of certain securities.

Entergy Gulf States Louisiana’s electric and gas business and Entergy Louisiana are subject to regulation by the LPSC as to:

·	utility service;

·	retail rates and charges;

·	certification of generating facilities;

·	certification of power or capacity purchase contracts;

·	audit of the fuel adjustment charge, environmental adjustment charge, and avoided cost payment to Qualifying Facilities;

·	integrated resource planning;

·	issuance and sale of certain securities;

·	utility mergers and acquisitions and other changes of control;

·	depreciation and other matters.

Entergy Louisiana is also subject to the jurisdiction of the City Council with respect to such matters within Algiers in Orleans Parish, although the precise scope of that jurisdiction differs from that of the LPSC.

Entergy Mississippi is subject to regulation by the MPSC as to the following:

·	utility service;

·	service areas;

·	facilities;

·	certification of certain transmission projects; and

·	retail rates.

Entergy Mississippi is also subject to regulation by the APSC as to the certificate of environmental compatibility and public need for the Independence Station, which is located in Arkansas.

Entergy New Orleans is subject to regulation by the City Council as to the following:

·	utility service;

·	retail rates and charges;

·	standards of service;

·	depreciation,

·	issuance and sale of certain securities; and

·	other matters.

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To the extent authorized by governing legislation, Entergy Texas is subject to the original jurisdiction of the municipal authorities of a number of incorporated cities in Texas with appellate jurisdiction over such matters residing in the PUCT. Entergy Texas is also subject to regulation by the PUCT as to:

·	retail rates and service in unincorporated areas of its service territory, and in municipalities that have ceded jurisdiction to the PUCT;

·	customer service standards;

·	certification of certain transmission projects; and

·	extensions of service into new areas.

Regulation of the Nuclear Power Industry

Atomic Energy Act of 1954 and Energy Reorganization Act of 1974

Under the Atomic Energy Act of 1954 and the Energy Reorganization Act of 1974, the operation of nuclear plants is heavily regulated by the NRC, which has broad power to impose licensing and safety-related requirements. The NRC has broad authority to impose fines or shut down a unit, or both, depending upon its assessment of the severity of the situation, until compliance is achieved. Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy, as owners of all or portions of ANO, River Bend, Waterford 3, and Grand Gulf, respectively, and Entergy Operations, as the licensee and operator of these units, are subject to the jurisdiction of the NRC. Entergy subsidiaries in the Entergy Wholesale Commodities segment are subject to the NRC’s jurisdiction as the owners and operator of Pilgrim, Indian Point Energy Center, FitzPatrick, Vermont Yankee, and Palisades. Substantial capital expenditures at Entergy’s nuclear plants because of revised safety requirements of the NRC could be required in the future.

Nuclear Waste Policy Act of 1982

Spent Nuclear Fuel

Under the Nuclear Waste Policy Act of 1982, the DOE is required, for a specified fee, to construct storage facilities for, and to dispose of, all spent nuclear fuel and other high-level radioactive waste generated by domestic nuclear power reactors. Entergy’s nuclear owner/licensee subsidiaries provide for the estimated future disposal costs of spent nuclear fuel in accordance with the Nuclear Waste Policy Act of 1982. The affected Entergy companies entered into contracts with the DOE, whereby the DOE is to furnish disposal services at a cost of one mill per net kWh generated and sold after April 7, 1983, plus a one-time fee for generation prior to that date. Entergy Arkansas is the only one of the Utility operating companies that generated electric power with nuclear fuel prior to that date and has a recorded liability as of December 31, 2011 of $181.0 million for the one-time fee. Entergy accepted assignment of the Pilgrim, FitzPatrick and Indian Point 3, Indian Point 1 and 2, Vermont Yankee, Palisades, and Big Rock Point spent fuel disposal contracts with the DOE held by their previous owners. The previous owners have paid or retained liability for the fees for all generation prior to the purchase dates of those plants. The fees payable to the DOE may be adjusted in the future to assure full recovery. Entergy considers all costs incurred for the disposal of spent nuclear fuel, except accrued interest, to be proper components of nuclear fuel expense. Provisions to recover such costs have been or will be made in applications to regulatory authorities for the Utility plants. Entergy’s total spent fuel fees to date, including the one-time fee liability of Entergy Arkansas, have almost reached $1.5 billion.

The permanent spent fuel repository in the U.S. has been legislated to be Yucca Mountain, Nevada. The DOE is required by law to proceed with the licensing (the DOE filed the license application in June 2008) and, after the license is granted by the NRC, proceed with the repository construction and commencement of receipt of spent fuel. Because the DOE has not begun accepting spent fuel, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts. The DOE continues to delay meeting its obligation. Moreover, the Obama administration has expressed its intention and taken specific steps to discontinue the Yucca

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Mountain project and study a new spent fuel strategy. Such actions include a motion to the NRC to withdraw the license application with prejudice and the establishment of a commission to develop recommendations for alternative spent fuel storage solutions. On June 29, 2010, however, a panel of the NRC’s Atomic Safety and Licensing Board denied the administration’s motion to withdraw the application. In November 2011 the NRC Commissioners issued an order effectively affirming the ASLB’s denial of the withdrawal, but the order also shut down the continued adjudication of the license application. Accordingly, large uncertainty remains regarding the time frame under which the DOE will begin to accept spent fuel from Entergy's facilities for storage or disposal. As a result, continuing future expenditures will be required to increase spent fuel storage capacity at Entergy's nuclear sites.

As a result of the DOE's failure to begin disposal of spent nuclear fuel in 1998 pursuant to the Nuclear Waste Policy Act of 1982 and the spent fuel disposal contracts, Entergy's nuclear owner/licensee subsidiaries have incurred and will continue to incur damages. In November 2003 these subsidiaries, except for the owner of Palisades, began litigation to recover the damages caused by the DOE's delay in performance. In October 2007, the U.S. Court of Federal Claims awarded $48.7 million jointly to System Fuels and Entergy Arkansas in damages related to the DOE's breach of its obligations. In a revised decision issued in March 2010, the court awarded $9.7 million jointly to System Fuels, System Energy, and SMEPA. Also in March 2010, in two separate decisions, the court awarded $106.1 million to Entergy Nuclear Indian Point 2, and $4.2 million to Entergy Nuclear Generation Company (the owner of Pilgrim). In September 2010 the court awarded $46.6 million to Entergy Nuclear Vermont Yankee. All of these decisions were appealed by the DOE to the U.S. Court of Appeals for the Federal Circuit. In September 2011, the appeals court affirmed most of the Entergy Nuclear Generation Company award, but remanded to the trial court for recalculation of certain damages. In January 2012 the appeals court affirmed the System Fuels and Entergy Arkansas award in large part, and reversed the trial court’s denial of certain damages sought, but remanded to the trial court for recalculation of certain damages. Also in January 2012, the appeals court affirmed the System Fuels, System Energy and SMEPA award, and reversed the trial court’s denial of certain damages, raising the final award to $10.2 million. Management cannot predict the timing or amount of any potential recoveries on other claims filed by Entergy subsidiaries, and cannot predict the timing of any eventual receipt from the DOE of the U.S. Court of Federal Claims damage awards.

Pending DOE acceptance and disposal of spent nuclear fuel, the owners of nuclear plants are providing their own spent fuel storage. Storage capability additions using dry casks began operations at Palisades in 1993, at ANO in 1996, at FitzPatrick in 2002, at River Bend in 2005, at Grand Gulf in 2006, at Indian Point and Vermont Yankee in 2008, and at Waterford 3 in 2011. These facilities will be expanded as needed. Current on-site spent fuel storage capacity at Pilgrim is estimated to be sufficient until approximately 2014, by which time dry cask storage facilities are planned to be placed into service at that unit.

Nuclear Plant Decommissioning

Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Texas, and System Energy are entitled to recover from customers through electric rates the estimated decommissioning costs for ANO, the portion of River Bend subject to retail rate regulation, Waterford 3, and Grand Gulf, respectively. These amounts are deposited in trust funds that can only be used for future decommissioning costs. Entergy periodically reviews and updates the estimated decommissioning costs to reflect inflation and changes in regulatory requirements and technology, and then makes applications to the regulatory authorities to reflect, in rates, the changes in projected decommissioning costs.

In 2008, Entergy experienced declines in the market value of assets held in the trust funds for meeting the decommissioning funding assurance obligations for the nuclear plants. This decline adversely affected certain Entergy subsidiaries’ abilities to demonstrate compliance with the NRC’s requirements for providing financial assurance for decommissioning funding for some of its plants. Following a review in 2009, Entergy concluded that there was a funding shortfall for Vermont Yankee of approximately $40 million, which it satisfied with a $40 million guarantee from Entergy Corporation that was effective as of December 31, 2009. For Waterford 3 and River Bend, Entergy subsidiaries made appropriate filings by December 31, 2009 with their retail regulators that requested decommissioning funding from customers to address the shortfalls identified by the NRC. On July 28, 2010, the LPSC approved increased decommissioning collections for Waterford 3 and the Louisiana regulated share of River Bend. On December 13, 2010, the PUCT approved increased decommissioning collections for the Texas share of River Bend. Entergy currently believes its decommissioning funding will be sufficient to address the identified shortfalls, although decommissioning cost inflation and trust fund performance will ultimately determine the adequacy of the funding amounts.

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Additional information with respect to Entergy’s decommissioning costs and decommissioning trust funds is found in Note 9 and Note 17 to the financial statements.

Price-Anderson Act

The Price-Anderson Act requires that reactor licensees purchase insurance and participate in a secondary insurance pool that provides insurance coverage for the public in the event of a nuclear power plant accident. The costs of this insurance are borne by the nuclear power industry. Congress amended and renewed the Price-Anderson Act in 2005 for a term through 2025. The Price-Anderson Act limits contingent liability for a single nuclear incident to approximately $117.5 million per reactor (with 104 nuclear industry reactors currently participating). Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, System Energy, and Entergy Wholesale Commodities have protection with respect to this liability through a combination of private insurance and an industry assessment program, as well as insurance for property damage, costs of replacement power, and other risks relating to nuclear generating units. The Price-Anderson Act and insurance applicable to the nuclear programs of Entergy are discussed in more detail in Note 8 to the financial statements.

Environmental Regulation

Entergy’s facilities and operations are subject to regulation by various governmental authorities having jurisdiction over air quality, water quality, control of toxic substances and hazardous and solid wastes, and other environmental matters. Management believes that Entergy’s businesses are in substantial compliance with environmental regulations currently applicable to its facilities and operations. Because environmental regulations are subject to change, future compliance requirements and costs cannot be precisely estimated. Except to the extent discussed below, at this time compliance with federal, state, and local provisions regulating the discharge of materials into the environment, or otherwise protecting the environment, is incorporated into the routine cost structure of Entergy’s businesses and is not expected to have a material effect on their competitive position, results of operations, cash flows or financial position.

Clean Air Act and Subsequent Amendments

The Clean Air Act and its amendments establish several programs that currently or in the future may affect Entergy’s fossil-fueled generation facilities and, to a much lesser extent, certain operations at nuclear and other facilities. Individual states also operate similar independent state programs or delegated federal programs that may include requirements more stringent than federal regulatory requirements. These programs include:

·	New source review and preconstruction permits for new sources of criteria air pollutants and significant modifications to existing facilities;

·	Acid rain program for control of sulfur dioxide (SO2) and nitrogen oxides (NOx);

·	Nonattainment area programs for control of criteria air pollutants;

·	Hazardous air pollutant emissions reduction programs;

·	Interstate Air Transport;

·	Operating permits program for administration and enforcement of these and other Clean Air Act programs; and

·	Regional Haze and Best Available Retrofit Technology programs.

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New Source Review (NSR)

Preconstruction permits are required for new facilities and for existing facilities that undergo a modification that results in a significant net emissions increase and is not classified as routine repair, maintenance, or replacement. Units that undergo a non-routine modification must obtain a permit modification and may be required to install additional air pollution control technologies. Entergy has an established process for identifying modifications requiring additional permitting approval and has followed the regulations and associated guidance provided by the states and the federal government with regard to the determination of routine repair, maintenance, and replacement. In recent years, however, the EPA has begun an enforcement initiative, aimed primarily at coal plants, to identify modifications that it does not consider routine for which the unit did not obtain a modified permit. Various courts and the EPA have been inconsistent in their judgments regarding modifications that are considered routine.

In September 2010 the owner of a minority interest in Entergy’s White Bluff and Independence facilities, both located in Arkansas, received a request from the EPA for several categories of information concerning capital and maintenance projects at the facilities in order to determine compliance with the Clean Air Act. The EPA request for information does not allege that either facility violated the law. In February 2011, Entergy received a similar request from the EPA and has responded to it. In August 2011, Entergy’s Nelson facility, located in Louisiana, received a similar request for information from the EPA. Entergy responded to this request.

Acid Rain Program

The Clean Air Act provides SO2 allowances to most of the affected Entergy generating units for emissions based upon past emission levels and operating characteristics. Each allowance is an entitlement to emit one ton of SO2 per year. Plant owners are required to possess allowances for SO2 emissions from affected generating units. Virtually all Entergy fossil-fueled generating units are subject to SO2 allowance requirements. Entergy could be required to purchase additional allowances when it generates power using fuel oil. Fuel oil usage is determined by economic dispatch and influenced by the price of natural gas, incremental emission allowance costs, and the availability and cost of purchased power.

Ozone Nonattainment

Entergy Texas operates one fossil-fueled generating unit (Lewis Creek) in a geographic area that is not in attainment of the currently-enforced national ambient air quality standards for ozone. The nonattainment area that affects Entergy Texas is the Houston-Galveston-Brazoria area. Areas in nonattainment are classified as "marginal," "moderate," "serious," or "severe." When an area fails to meet the ambient air standard, the EPA requires state regulatory authorities to prepare state implementation plans meant to cause progress toward bringing the area into attainment with applicable standards.

The Houston-Galveston-Brazoria area was originally classified as "moderate" nonattainment under the 8-hour standard with an attainment date of June 15, 2010. On June 15, 2007, the Texas governor petitioned the EPA to reclassify Houston-Galveston-Brazoria from "moderate" to "severe." On October 1, 2008, the EPA granted the request by the Texas governor to voluntarily reclassify the Houston-Galveston-Brazoria area from a "moderate" 8-hour ozone nonattainment area to a "severe" 8-hour ozone nonattainment area. The EPA also set April 15, 2010, as the date for the State of Texas to submit a revised state implementation plan (SIP) addressing the "severe" ozone nonattainment area requirements of the Clean Air Act. In March 2010 the Texas commission adopted the Houston-Galveston-Brazoria Attainment Demonstration SIP Revision and the Houston-Galveston-Brazoria Reasonable Further Progress SIP Revision for the 1997 eight-hour ozone standard and associated rules. EPA approval is pending. The area's new attainment date for the 8-hour ozone standard is as expeditiously as practicable, but no later than June 15, 2019.

Entergy Gulf States Louisiana operates two fossil-fueled generating facilities in the Baton Rouge metropolitan area which was previously classified as a non-attainment area for the 1997 eight-hour ozone standard. However, in November 2011, the EPA finalized approval of Louisiana’s request to redesignate the Baton Rouge area to attainment for this standard. Louisiana has demonstrated that the five parish area (East Baton Rouge, Ascension, Iberville, Livingston and West Baton Rouge parishes) will be able to maintain compliance with the ozone standard for the next ten years.

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In December 2006, the EPA's revocation of the 1-hour ozone standard was rejected in a judicial proceeding. As a result, numerous requirements can return for areas that had been designated as nonattainment for this standard. These requirements include the potential to increase emission fees significantly for plants operating in these areas pursuant to Section 185 of the Clean Air Act. In addition, it is possible that new emission controls may be required. Specific costs of compliance cannot be estimated at this time, but Entergy is monitoring development of the respective state implementation plans and will develop specific compliance strategies as the plans move through the adoption process. (The Houston-Galveston-Brazoria area was classified as “severe” nonattainment for 1-hour ozone.)

In March 2008, the EPA revised the National Ambient Air Quality Standard for ozone, creating the potential for additional counties and parishes in which Entergy operates to be placed in nonattainment status. The LDEQ recommended that eleven parishes be designated as nonattainment for the 75 parts per billion ozone standard. Entergy Gulf States Louisiana owns and operates two fossil plants and Entergy Louisiana owns and operates one fossil plant affected by this recommendation. In Arkansas, the governor recommended that Pulaski County be designated in nonattainment with the new ozone standard, where two of Entergy Arkansas’s smaller facilities are located. These initial recommendations were not approved by the EPA, however, due to various procedural delays. In September 2011, the EPA announced that it will begin implementing the 2008 ozone standards by requiring that states resubmit recommendations for nonattainment status. In Entergy’s utility service area, EPA predicts that the Houston-Galveston-Brazoria, Texas; Baton Rouge, Louisiana; and Memphis, Tennessee/Arkansas areas will be in non-attainment. Nonattainment designations are expected to be final in mid-2012.

Following nonattainment designation, states will be required to develop state implementation plans that outline control requirements that will enable the affected counties and parishes to reach attainment status. Entergy facilities in these areas may be subject to installation of NOx controls, but the degree of control will remain unknown until the state implementation plans are developed. Entergy will continue to monitor and engage in the state implementation plan development process in Entergy states.

Potential SO2 Nonattainment

The EPA issued a final rule in June 2010 adopting an SO2 1-hour national ambient air quality standard of 75 ppb. The EPA designations for counties in attainment and nonattainment are expected in June 2012. Analysis will be required to determine whether emissions from Entergy facilities contribute significantly to any violation of this new standard. If violations exist, additional capital projects or operational changes may be required.

Hazardous Air Pollutants

The EPA has been in the process of developing a Maximum Achievable Control Technology (MACT) retrofit standard for new and existing coal and oil-fired units. The EPA released the final Mercury and Air Toxics Standard (MATS) rule in December 2011. Entergy currently is reviewing the rule and developing compliance plans to meet requirements of the rule, which could result in significant capital expenditures for Entergy’s coal-fired units. Compliance with MATS is required by the Clean Air Act within three years, or by 2015, although certain extensions of this deadline are available from state permit authorities and the EPA.

Interstate Air Transport

In March 2005, the EPA finalized the Clean Air Interstate Rule (CAIR), which was intended to reduce SO2 and NOx emissions from electric generation plants in order to improve air quality in twenty-nine eastern states. The rule required a combination of investment of capital to install pollution control equipment and increased operating costs through the purchase of emission allowances. Entergy began implementation in 2007, including installation of controls at several facilities and the development of an emission allowance procurement strategy.

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Based on several court challenges, the CAIR was vacated and remanded to the EPA by the D.C. Circuit in 2008. The court allowed the CAIR to become effective in January 2009, while the EPA revised the rule. On July 7, 2011, the EPA released its final Cross-State Air Pollution Rule (CSAPR, which previously was referred to as the Transport Rule). The rule is directed at limiting the interstate transport of emissions of NOx and SO2 as precursors to ozone and fine particulate matter. The final rule provides a significantly lower number of allowances to Entergy’s Utility states than did the draft rule. Entergy’s capital investment and annual allowance purchase costs under the CSAPR will depend on the economic assessment of NOx and SO2 allowance markets, the cost of control technologies, generation unit utilization, and the availability and cost of purchased power.

Entergy filed a petition for review with the United States Court of Appeals for the D.C. Circuit and a petition with the EPA for reconsideration of the rule and stay of its effectiveness. Several other parties filed similar petitions. On December 30, 2011, the D.C. Circuit Court of Appeals stayed CSAPR and instructed EPA to continue administering CAIR, pending further judicial review. Oral argument in the case is scheduled for April 2012. The court of appeals may reverse or remand the rule in whole or in part, or may affirm the rule. This uncertainty makes it impossible to predict costs of compliance. In the interim, Entergy is taking measures to prepare for compliance with either CAIR as it continues to be implemented or CSAPR, if it is affirmed in whole or in part or eventually reissued.

In October 2011 the EPA released a proposed rule increasing the emission allocation budgets for some states and moving the limited trading period back to 2014. This proposal also increased the Louisiana, Mississippi, and Texas NOx allocation budgets. The EPA has not finalized this proposal.

Regional Haze

In June 2005, the EPA issued final Best Available Retrofit Control Technology (BART) regulations that could potentially result in a requirement to install SO2 and NOx pollution control technology on certain of Entergy’s coal and oil generation units. The rule leaves certain BART determinations to the states. The Arkansas Department of Environmental Quality (ADEQ) prepared a State Implementation Plan (SIP) for Arkansas facilities to implement its obligations under the Clean Air Visibility Rule. The ADEQ determined that Entergy Arkansas’s White Bluff power plant affects a Class I Area’s visibility and will be subject to the EPA’s presumptive BART limits, which likely would require the installation of scrubbers and low NOx burners. Under then-current state regulations, the scrubbers would have had to be operational by October 2013. Entergy Arkansas filed a petition in December 2009 with the Arkansas Pollution Control and Ecology Commission requesting a variance from this deadline, however, because the EPA has expressed concerns about Arkansas’s Regional Haze SIP and questioned the appropriateness of issuing an air permit prior to that approval. EAI’s petition requested that, consistent with federal law, the compliance deadline be changed to as expeditiously as practicable, but in no event later than five years after EPA approval of the Arkansas Regional Haze SIP. The Arkansas Pollution Control and Ecology Commission approved the variance in March 2010. In October 2011 the EPA released a proposed rule addressing the Arkansas Regional Haze SIP. In the proposal the EPA disapproves a large portion of the Arkansas Regional Haze SIP, including the emission limits for NOx and SO2 at White Bluff. The EPA did not issue a Federal Implementation Plan for regional haze requirements because Arkansas has indicated it wishes to correct its SIP and resubmit it. Due to an extension in the comment period for the proposed rule, EPA has yet to issue a final rule. It is expected that after the EPA’s proposed rule becomes final, there will be a two-year timeframe in which the EPA must either approve a SIP issued by Arkansas or issue a Federal Implementation Plan.

Potential Legislative, Regulatory, and Judicial Developments (Air)

In addition to the specific instances described above, there are a number of legislative and regulatory initiatives relating to the reduction of emissions that are under consideration at the federal, state, and local level. Because of the nature of Entergy’s business, the imposition of any of these initiatives could affect Entergy’s operations. Entergy continues to monitor these initiatives and activities in order to analyze their potential operational and cost implications. These initiatives include:

·	designation by the EPA and state environmental agencies of areas that are not in attainment with national ambient air quality standards;

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introduction of bills in Congress and development of regulations by the EPA proposing further limits on NOx, SO2, mercury, and carbon dioxide and other gas emissions. New legislation or regulations applicable to stationary sources could take the form of market-based cap-and-trade programs, direct requirements for the installation of air emission controls onto air emission sources, or other or combined regulatory programs. Entergy cannot estimate the effect of any future legislation at this time due to the uncertainty of the regulatory format;

·	efforts to implement a voluntary program intended to reduce carbon dioxide emissions and efforts in Congress to establish a mandatory federal carbon dioxide emission control structure;

·	passage and implementation of the Regional Greenhouse Gas Initiative by several states in the northeastern United States and similar actions in other regions of the United States;

·	efforts on the state and federal level to codify renewable portfolio standards requiring utilities to produce or purchase a certain percentage of their power from defined renewable energy sources;

·	efforts to develop more stringent state water quality standards, effluent limitations for Entergy’s industry sector, stormwater runoff control regulations, and cooling water intake structure requirements; and

efforts by certain external groups to encourage reporting and disclosure of carbon dioxide emissions and risk. Entergy has prepared responses for the Carbon Disclosure Project’s (CDP) annual questionnaire for the past several years and has given permission for those responses to be posted to CDP’s website.

In addition to these initiatives, certain states and environmental advocacy groups sought judicial action to require the EPA to promulgate regulations under existing provisions of the Clean Air Act to control carbon dioxide emissions from power plants. In April 2007 the U.S. Supreme Court held that the EPA is authorized by the current provisions of the Clean Air Act to regulate emissions of carbon dioxide and other “greenhouse gases” as “pollutants” (Massachusetts v. EPA) and that the EPA is required to regulate these emissions from motor vehicles if the emissions are anticipated to endanger public health or welfare. The Supreme Court directed the EPA to make further findings in this regard. Entergy participated as a friend of the court in Massachusetts v. EPA. Entergy will continue to advocate in support of reasonable market-based regulation of carbon dioxide. Entergy has also supported the comments of various industry groups advocating national legislation to address carbon dioxide emissions instead of attempting to regulate under the provisions of the Clean Air Act. Entergy continues to monitor these and similar actions in order to analyze their potential operational and cost implications and benefits.

In 2009 the EPA published an “endangerment finding” stating that the emission of “greenhouse” gases “may reasonably be anticipated to endanger public health or welfare” and that the emission of these pollutants from mobile sources (such as cars and trucks) contributes to this endangerment. The EPA issued final mobile source emission regulations on April 1, 2010. On April 2, 2010, the EPA issued a policy stating that the regulation of greenhouse gas emissions from mobile sources would, as of January 2, 2011 (the date that the mobile source rule “takes effect”), trigger the regulation of greenhouse gases from stationary sources under the Prevention of Significant Deterioration (PSD) and Title V programs of the Clean Air Act.

In June 2010 the EPA published the final Tailoring Rule outlining the applicability criteria that determine which stationary sources and modification projects become subject to permitting requirements for greenhouse gas emissions under the Clean Air Act. The Tailoring Rule establishes a two-step process for implementing regulation of greenhouse gas emissions under the PSD and Title V programs. The first step, which began on January 2, 2011, limits the applicability of the PSD and Title V requirements for greenhouse gas emissions to sources that are already subject to PSD and Title V based on the emission of non-greenhouse gas pollutants. Specifically, projects undertaken at stationary sources will trigger PSD permitting requirements if the project increases net greenhouse gas emissions by at least 75,000 tons per year carbon dioxide equivalent and significantly increases emissions of at least one non-greenhouse gas pollutant. During step one, only sources subject to Title V based on their emission of non-greenhouse gas pollutants were required to address greenhouse gas emissions in their Title V permit.

The second step of the Tailoring Rule, which began on July 1, 2011, subjects to Title V requirements any new or existing source not already subject to Title V that emits, or has the potential to emit, at least 100,000 tons per year carbon dioxide equivalent. In addition, new sources that have the potential to emit at least 100,000 tons per year carbon dioxide equivalent and significantly modified existing sources that emit or have the potential to emit at least 75,000 tons per year carbon dioxide equivalent are subject to PSD requirements.

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Both the Endangerment Finding and the Tailoring Rule are subject to pending judicial review. The rules have not been stayed by the court and are in effect pending review.

Entergy continues to support national legislation that would increase planning certainty for electric utilities while addressing carbon dioxide emissions in a responsible and flexible manner. By virtue of its proportionally large investment in low- or non-emitting gas-fired and nuclear generation technologies, Entergy has a low overall carbon dioxide emission “intensity,” or rate of carbon dioxide emitted per kilowatt-hour of electricity generated. In anticipation of the potential imposition of carbon dioxide emission limits on the electric industry in the future, Entergy initiated actions designed to reduce its exposure to potential new governmental requirements related to carbon dioxide emissions. These voluntary actions included establishment of a formal program to stabilize power plant carbon dioxide emissions at 2000 levels through 2005, and Entergy succeeded in actually reducing emissions below 2000 levels. Total carbon dioxide emissions representing Entergy’s ownership share of power plants in the United States were approximately 53.2 million tons in 2000 and 35.6 million tons in 2005. In 2006, Entergy changed its method of calculating emissions and now includes emissions from controllable power purchases as well as its ownership share of generation. Entergy established a second formal voluntary program to stabilize power plant carbon dioxide emissions and emissions from controllable power purchases at 20% below 2000 levels through 2010. Entergy has extended this commitment through 2020. Total carbon dioxide emissions representing Entergy’s ownership share of power plants and controllable power purchases in the United States were approximately 44.9 million tons in 2010 and approximately 46.3 million tons in 2011.

Greenhouse Gas Reporting

In September 2009, the EPA finalized a rule to require reporting of several greenhouse gases. This rule will require Entergy to report annually greenhouse gas emissions from operating power plants and natural gas distribution operations. Entergy developed compliance plans, collected the necessary data, and reported as required in 2011.

New Source Performance Standards for Greenhouse Gas Emissions

The EPA announced a schedule for establishing new source performance standards (NSPS) for greenhouse gas (GHG) emissions from power plants and refineries. Under the schedule, the EPA would have issued proposed regulations for power plants by July 26, 2011 and final regulations no later than May 26, 2012. However, the EPA has not yet issued the proposed regulations. These regulations would establish GHG NSPS for new and significantly modified sources, and possibly emission guidelines for existing sources. Entergy will continue to monitor and be engaged in the rulemaking process.

Nelson Unit 6 (Entergy Gulf States Louisiana)

Entergy Gulf States Louisiana self-reported to the Louisiana Department of Environmental Quality (LDEQ) potential exceedances of annual carbon monoxide emission limits at the Nelson Unit 6 coal-fired facility for the years 2006-2010 and the failure to report these potential exceedances in semi-annual reporting and in annual Title V compliance certifications. Entergy Gulf States Louisiana is not required to monitor carbon monoxide emissions from Nelson Unit 6 on a regular or continuous schedule. Stack tests performed in 2010 appear to indicate carbon monoxide emissions in excess of the maximum hourly limit for three 1-hour test runs and the annual limit. Comparison of the 2010 stack tests with the most recent previous tests from 2006, however, appear to indicate that the permit limits were calculated incorrectly and should have been higher. The 2010 test emission levels did not cause a violation of National Ambient Air Quality Standards. Additionally, the 2010 stack testing, which was performed in compliance with an EPA data request connected to the EPA’s development of a new air emissions rule, was not taken during a period of normal and representative operations for Nelson Unit 6. Entergy Gulf States Louisiana continues to develop data regarding this matter in coordination with the LDEQ. In December 2011, the LDEQ issued a compliance order setting limits for the unit until and if the permit is modified and issued a notice of potential penalty requiring the submission of additional information.

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Clean Water Act

The 1972 amendments to the Federal Water Pollution Control Act (known as the Clean Water Act) provide the statutory basis for the National Pollutant Discharge Elimination System (NPDES) permit program and the basic structure for regulating the discharge of pollutants from point sources to waters of the United States. The Clean Water Act requires virtually all discharges of pollutants to waters of the United States to be permitted. Section 316(b) of the Clean Water Act regulates cooling water intake structures, section 401 of the Clean Water Act requires a water quality certification from the state in support of certain federal actions and approvals, and section 404 regulates the dredge and fill of waters of the United States, including jurisdictional wetlands.

NPDES Permits and Section 401 Water Quality Certifications

NPDES permits are subject to renewal every five years. Consequently, Entergy is currently in various stages of the data evaluation and discharge permitting process for its power plants. Additionally, the State of New York (and more recently, Vermont) has taken the position that a new state-issued water quality certification is required as part of the NRC license renewal process. Entergy Wholesale Commodities’ Indian Point nuclear facility in New York is seeking a new section 401 certification prior to license renewal under full reservation of rights.

Indian Point

Entergy is involved in an administrative permitting process with the New York State Department of Environmental Conservation (NYSDEC) for renewal of the Indian Point 2 and Indian Point 3 discharge permits. In November 2003, the NYSDEC issued a draft permit indicating that closed cycle cooling would be considered the “best technology available” for minimizing alleged adverse environmental effects attributable to the intake of cooling water at Indian Point, subject to a feasibility determination and alternatives analysis for that technology, if Entergy applied for and received NRC license renewal for Indian Point 2 and Indian Point 3. Upon becoming effective, the draft permit also would have required payment of approximately $24 million annually, and an annual 42 unit-day outage period, until closed cycle cooling is implemented. Entergy is participating in the administrative process to request that the draft permit be modified prior to final issuance, and opposes any requirement to install cooling towers at Indian Point.

An August 2008 ruling by the NYSDEC’s Assistant Commissioner has restructured the permitting and administrative process, including the application of a new economic test designed to implement the U.S. Second Circuit Court of Appeals standard in that court’s review of EPA’s cooling water intake structure rules, which is discussed in the 316(b) Cooling Water Intake Structures section below. The NYSDEC has directed Entergy to develop detailed feasibility information regarding the construction and operation of cooling towers, and alternatives to closed cycle cooling, prior to the issuance of a new draft permit by the NYSDEC staff and commencement of the adjudicatory proceeding. The reports include a visual impact and aesthetics report filed in June 2009, a plume and emissions report filed in September 2009, a technical feasibility report and alternatives analysis filed in February 2010, and an economic report to establish whether the technology, if feasible, satisfies the economic test that is part of the New York standard. Entergy has also requested that the Assistant Commissioner reconsider the New York standard in light of the U.S. Supreme Court decision reversing the Second Circuit’s alternative economic test adopted in the August 2008 ruling.

In February 2010, Entergy provided to the NYSDEC an updated estimate of the capital cost to retrofit Indian Point 2 and Indian Point 3 with cooling towers. Construction costs for retrofitting with cooling towers are estimated to be at least $1.19 billion, in addition to lost generation of approximately 14.5 terawatt-hours (TWh) during the forced outage of both units that is estimated to take at least 42 weeks. Entergy also proposed an alternative to the cooling towers, the use of cylindrical wedgewire screens, the capital costs of which are currently expected to be approximately $200 million to $250 million to install. Because a cooling tower retrofitting of this size and complexity

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has never been undertaken at an operating nuclear facility, significant uncertainties exist in the capital cost estimates and, therefore, the actual capital costs could be materially higher than estimated. Moreover, construction outage-related costs to Entergy have not been calculated because of the significant variability in power pricing at any given time, but they are expected to be significant and may exceed the capital costs. The capital cost estimate for the wedgewire screen construction is also subject to uncertainty. Hearings on certain issues began in 2011 in consolidation with certain issues in the water quality certification matter that is discussed further below. The NYSDEC is expected to consider the information submitted and issue another draft permit with a new best technology available determination, which could still be cooling towers. A new comment period and further contested proceedings likely would follow.

Entergy submitted its application for a water quality certification to the NYSDEC in April 2009, with a reservation of rights regarding the applicability of Section 401 in this case. After Entergy submitted certain additional information in response to NYSDEC requests for additional information, in February 2010 the NYSDEC staff determined that Entergy’s water quality certification application was complete. In April 2010 the NYSDEC staff issued a proposed notice of denial of Entergy’s water quality certification application (the Notice). NYSDEC staff’s Notice triggered an administrative adjudicatory hearing before NYSDEC ALJs on the proposed Notice. The NYSDEC staff decision does not restrict Indian Point operations, but the issuance of a certification is potentially required prior to NRC issuance of renewed unit licenses.

In June 2011, Entergy filed notice with the NRC that the NYSDEC, the agency that would issue or deny a water quality certification for the Indian Point license renewal process, has taken longer than one year to take final action on Entergy’s application for a water quality certification and, therefore, has waived its opportunity to require a certification under the provisions of Section 401 of the Clean Water Act. The NYSDEC has notified the NRC that it disagrees with Entergy’s position and does not believe that it has waived the right to require a certification. The NYSDEC ALJs overseeing the agency’s certification adjudicatory process stated in a ruling issued in July 2011 that while the waiver issue is pending before the NRC, the NYSDEC hearing process will continue on selected issues. The judge held a Legislative Hearing (agency public comment session) and an Issues Conference (pre-trial conference) in July 2010 and set certain issues for trial in October 2011, which is continuing into 2012. After the full hearing on the merits, the ALJs will issue a recommended decision to the Commissioner who will then issue the final agency decision. A party to the proceeding can appeal the decision of the Commissioner to state court.

316(b) Cooling Water Intake Structures

EPA finalized regulations in July 2004 governing the intake of water at large existing power plants employing cooling water intake structures. The rule sought to reduce perceived impacts on aquatic resources by requiring covered facilities to implement technology or other measures to meet EPA-targeted reductions in water use and corresponding perceived aquatic impacts. Entergy, other industry members and industry groups, environmental groups, and a coalition of northeastern and mid-Atlantic states challenged various aspects of the rule. In January 2007, the U.S. Second Circuit Court of Appeals remanded the rule to the EPA for reconsideration. The court instructed the EPA to reconsider several aspects of the rule that were beneficial to businesses affected by the rule after finding that these provisions of the rule were contrary to the language of the Clean Water Act or were not sufficiently explained in the rule. In April 2008, the U.S. Supreme Court agreed to review the Second Circuit decision on the question of whether the EPA may take into consideration a cost-benefit analysis in developing these regulations, a consideration of potential benefit to businesses affected by the rule that the Second Circuit disallowed. In March 2009, the Supreme Court ruled in favor of the petitioners that cost-benefit analysis may be taken into consideration. The EPA reissued the proposed rule in April 2011, with finalization anticipated by July 27, 2012. Entergy filed comments with the EPA on the proposed rule.

At the request of the EPA Region 1 (Boston), Entergy submitted extensive data to the agency in July 2008 concerning cooling water intake impacts at the Pilgrim nuclear power plant. The Engineering Study, included as part of the July 2008 submittal, concluded that cooling towers are not feasible due to restrictions in the plant's condenser design and capacity. Other technologies, such as variable speed pumps and the relocation of the cooling water intake, were also analyzed as part of that submittal. EPA has not yet responded to the July 2008 submittal.

Entergy will continue to review the revised proposed rule and monitor the activities of the EPA and the states toward the implementation of section 316(b) of the Clean Water Act. Until analysis of this revised proposed rule is complete, deadlines for determining compliance with Section 316(b) and for any required capital or operational expenditures are unknown at this time. As a result, management cannot predict the amounts Entergy will ultimately be required to spend to comply with Section 316(b) and any related state regulations, although such amounts could be significant.

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Coastal Zone Management Act

The Coastal Zone Management Act (CZMA) requires federally-permitted activities within a coastal zone to be consistent with the state’s federally-approved coastal zone management program. Accordingly, Entergy must ensure that the requirements of the CZMA, which is administered in New York primarily by the New York Department of State, are satisfied before the NRC may issue renewed licenses for Indian Point 2 and 3. Indian Point expects to file its consistency determination application with the New York Department of State in 2012. When the application is deemed complete, the New York Department of State has six months from the date of the application to issue or deny the consistency certification.

Groundwater at Certain Nuclear Sites

The NRC requires nuclear power plants to regularly monitor and report the presence of radioactive material in the environment. Entergy joined other nuclear utilities and the Nuclear Energy Institute in 2006 to develop a voluntary groundwater monitoring and protection program. This initiative began after detection of very low levels of radioactive material, primarily tritium, in groundwater at several plants in the United States. Tritium is a radioactive form of hydrogen that occurs naturally and is also a byproduct of nuclear plant operations. In addition to tritium, other radionuclides have been found in on site ground water at nuclear plants.

As part of the groundwater monitoring and protection program, Entergy has: (1) performed reviews of plant groundwater characteristics (hydrology) and historical records of past events on site that may have potentially impacted groundwater; (2) implemented fleet procedures on how to handle events that could impact groundwater; and (3) installed groundwater monitoring wells and began periodic sampling. The program also includes protocols for notifying local officials if contamination is found. To date, radionuclides such as tritium have been detected at Entergy’s FitzPatrick, Indian Point, Palisades, Pilgrim, Grand Gulf, Vermont Yankee, and River Bend plants. Based on current information, the concentrations and locations of tritium detected at these plants pose no threat to public health or safety.

At FitzPatrick, twenty-one (21) monitoring wells are installed and being routinely monitored for tritium and other radioisotopes. Tritium and Strontium-90 have been detected in several of these wells at trace concentrations well below the EPA drinking water standard. A more significant concentration of tritium was identified in the reactor building perimeter drain piping and associated collection sump. The site identified the sources as a piping leak that subsequently migrated to the environment via a failed concrete expansion joint. Repairs to the piping system were completed in September 2010. There are no drinking water wells on-site.

Entergy identified and addressed two sources of the contamination at Indian Point: the Unit 1 and 2 spent fuel pools. In October 2007, the EPA announced that it was consulting with the NRC and the NYSDEC regarding Indian Point. The EPA stated that after reviewing data it confirmed with New York State that there have been no violations of federal drinking water standards for radionuclides in drinking water supplies. Indian Point has implemented an extensive groundwater monitoring and protection program, including installing approximately 35 monitoring wells. Entergy has been working cooperatively with the NRC and the NYSDEC in a split sample program to independently analyze test samples.

At Palisades, Entergy identified tritium in two groundwater monitoring wells in December 2007 caused by leakage from the buried piping for a recirculation line. Following investigation and repair work on this line, the decision was made to abandon the line and install new, replacement buried pipe for this system. This effort was completed in December 2009. Groundwater from three site monitoring wells continued to show positive detections of tritium resulting in renewed investigation and subsequent piping repair during May 2011. Monitoring wells are being sampled and analyzed on a bi-weekly basis and remaining site monitoring wells are being sampled and analyzed quarterly.

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At Pilgrim, 18 monitoring wells are being sampled and analyzed on a routine basis. Results continue to show low levels of tritium. A hydrogeological analysis was performed in 2009 to pinpoint locations for additional evaluation wells, and these wells were installed in 2010. Tritium was discovered in two onsite wells. Investigations are underway to determine the source of the tritium, and split sampling is being performed routinely with the State of Massachusetts. In order to further its tritium investigations, Pilgrim added two more groundwater monitoring wells in December 2011, bringing the total number of monitoring wells to 20. The Pilgrim tritium technical team meets twice per week to discuss investigative options and weekly update calls are held with the Massachusetts Department of Public Health.

At Grand Gulf, groundwater samples collected in June 2010 and thereafter have revealed the presence of low-level tritium. These groundwater detections are believed to be from a leak of a temporary chiller unit that occurred in 1997. The leak was detected and halted in 1997, but approximately 1,200 gallons of water spilled from the temporary chiller unit. In addition to these groundwater samples, certain surface water samples at Grand Gulf also have detected the presence of low-level tritium. These surface water detections are believed to be from tritium recapture from atmospheric deposition; however, further analysis and investigation are taking place to determine the cause of all the tritium detections.

In January 2010, Vermont Yankee was notified by its off-site analytical laboratory that a sample collected from a groundwater monitoring well in mid-November 2009 showed elevated levels of tritium. In March 2010, Vermont Yankee announced that it had identified the source of the tritium leakage at the plant, and that it had stopped the leakage. Remediation of the soil is complete and groundwater remediation is ongoing. In September 2011 the NRC concluded that Vermont Yankee had complied with all applicable regulatory requirements and standards pertaining to radiological effluent monitoring, dose and assessment and radiological evaluation. It also found that there has been no impact on public health and safety due to the groundwater contamination event that led to the detection of tritium in groundwater samples in January 2010.

In February 2010 the Vermont Public Service Board (VPSB) began a proceeding to conduct an investigation into whether Vermont Yankee should be required to cease operations, or take other ameliorative actions, pending completion of repairs to stop releases of tritium or other radionuclides into the environment. This investigation will also consider whether good cause exists to modify or revoke the Vermont Yankee certificate of public good that the VPSB issued in 2002 and whether any penalties should be imposed on Vermont Yankee for any identified violations of Vermont statutes or VPSB orders related to those releases. The proceeding and VPSB investigation were opened prior to Vermont Yankee locating the source and beginning the remediation of the tritium leaking into groundwater at the site. The VPSB conceded in its order that its jurisdiction to impose some or all of the relief requested may be preempted by federal law or regulation, and the parties were asked to brief preemption issues during the initial phase of the proceeding. Initial and reply briefs on the issue of the VPSB’s jurisdiction were filed by the parties, including Vermont Yankee, in August and September 2010. The VPSB held evidentiary hearings in January 2011 on the facts of the tritium leakage and remediation and on various parties’ requests for relief. There is no schedule for decision by the VPSB on jurisdiction or other issues.

In December 2011, River Bend sampled a groundwater well previously installed for the purpose of collecting groundwater elevation measurements. The sample revealed the presence of tritium above the drinking water threshold set by the EPA. No groundwater wells are used for drinking on-site and tritium was not detected in any wells downgradient or surrounding this well. Notification was made to the NRC, as well as to state and local agencies. Entergy is performing an evaluation and review of this condition.

Indian Point Units 1 and 2 Hazardous Waste Remediation

As part of the effort to terminate the current Indian Point 2 mixed waste storage permit, Entergy was required to perform groundwater and soil sampling for metals, PCBs and other non-radiological contaminants on plant property, regardless of whether these contaminants stem from onsite activities or were related to the waste stored on-site pursuant to the permit. Entergy believes this permit is no longer necessary for the facility due to an exemption for mixed wastes (hazardous waste that is also radioactive) promulgated as part of the EPA’s hazardous waste regulations. This exemption allows mixed waste to be regulated through the NRC license instead of through a separate

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EPA or state hazardous waste permit. In February 2008, Entergy submitted its report on this sampling effort to the NYSDEC. The report indicated the presence of various metals in soils and groundwater at levels above the NYSDEC cleanup objectives. It does not appear that these metals are connected to operation of the nuclear facility. At the request of the NYSDEC, Entergy submitted a plan in August 2008 for a study that identified the sources of the metals. The NYSDEC approved the work plan with some conditions related to the need to study whether the soil impact observed may have originated from plant construction materials. Entergy has conducted additional sampling and currently is evaluating the results in order to provide additional information to the NYSDEC. Entergy is unable to determine what the extent or cost of required remediation, if any, will be at this time.

Prior to Entergy’s purchase of Indian Point Unit 1, the previous owner completed the cleanup and desludging of the Unit 1 water storage pool, generating mixed waste. The waste currently is stored in the Unit 1 containment building in accordance with NRC regulations controlling low level radioactive waste. The waste is also regulated by the NYSDEC. The NYSDEC requires a quarterly survey of the availability of any commercial facility capable of treating, processing, and disposing of this waste in a commercially reasonable manner. Entergy continues to review this matter and to conduct its quarterly searches for a commercially reasonable vendor that is acceptable both to the NRC and the NYSDEC. The cost of this disposal cannot be estimated at this time due to the many variables existing in the type and manner of disposal.

Comprehensive Environmental Response, Compensation, and Liability Act of 1980

The Comprehensive Environmental Response, Compensation, and Liability Act of 1980, as amended (CERCLA), authorizes the EPA to mandate clean-up by, or to collect reimbursement of clean-up costs from, owners or operators of sites at which hazardous substances may be or have been released. Certain private parties also may use CERCLA to recover response costs. Parties that transported hazardous substances to these sites or arranged for the disposal of the substances are also deemed liable by CERCLA. CERCLA has been interpreted to impose strict, joint and several liability on responsible parties. Entergy subsidiaries in the Utility and Entergy Wholesale Commodities businesses have sent waste materials to various disposal sites over the years, and releases have occurred at Entergy facilities. In addition, environmental laws now regulate certain of Entergy’s operating procedures and maintenance practices that historically were not subject to regulation. Some disposal sites used by Entergy subsidiaries have been the subject of governmental action under CERCLA, resulting in site clean-up activities. Entergy subsidiaries have participated to various degrees in accordance with their respective potential liabilities in such site clean-ups and have developed experience with clean-up costs. The affected Entergy subsidiaries have established provisions for the liabilities for such environmental clean-up and restoration activities. Details of CERCLA liabilities that are not de minimis are discussed in the “Other Environmental Matters” section below.

Coal Combustion Residuals

In June 2010 the EPA issued a proposed rule on coal combustion residuals (CCRs) that contains two primary regulatory options: (1) regulating CCRs destined for disposal in landfills or received (including stored) in surface impoundments as so-called “special wastes” under the hazardous waste program of RCRA Subtitle C; or (2) regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes under Subtitle D of RCRA. Under both options, CCRs that are beneficially used in certain processes would remain excluded from hazardous waste regulation.

The proposed regulations would create new compliance requirements including modified storage, new notification and reporting practices, new financial assurance requirements, and product disposal considerations. According to EPA estimates, the annualized cost of on-site disposal under the two proposals would be $3.6 million to $9 million for the White Bluff and Independence facilities and $1.7 million to $3.3 million for the Nelson Unit 6 facility. If Entergy utilized off-site disposal, which it would not plan to do, the EPA’s total cost estimates for disposal of CCRs under Subtitle C regulation ranges from $250 to $350 million per year.

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Other Environmental Matters

Entergy Gulf States Louisiana and Entergy Texas

Several class action and other suits have been filed in state and federal courts seeking relief from Entergy Gulf States, Inc. and others for damages caused by the disposal of hazardous waste and for asbestos-related disease allegedly resulting from exposure on Entergy Gulf States, Inc.’s premises (see “Litigation” below).

Entergy Gulf States Louisiana is currently involved in the second phase of the remedial investigation of the Lake Charles Service Center site, located in Lake Charles, Louisiana. A manufactured gas plant (MGP) is believed to have operated at this site from approximately 1916 to 1931. Coal tar, a by-product of the distillation process employed at MGPs, was apparently routed to a portion of the property for disposal. The same area has also been used as a landfill. In 1999, Entergy Gulf States, Inc. signed a second administrative consent order with the EPA to perform removal action at the site. In 2002, approximately 7,400 tons of contaminated soil and debris were excavated and disposed of from an area within the service center. In 2003, a cap was constructed over the remedial area to prevent the migration of contamination to the surface. In August 2005, an administrative order was issued by the EPA requiring that a 10-year groundwater study be conducted at this site. The groundwater monitoring study commenced in January 2006 and is continuing. Entergy Gulf States Louisiana and Entergy Texas each believe that its remaining responsibility for this site will not materially exceed the existing clean-up provisions of $0.5 million for Entergy Gulf States Louisiana and $0.4 million for Entergy Texas.

In 1994, Entergy Gulf States, Inc. performed a site assessment in conjunction with a construction project at the Louisiana Station Generating Plant (Louisiana Station). In 1995, a further assessment confirmed subsurface soil and groundwater impact to three areas on the plant site. After validation, a notification was made to the LDEQ and a phased process was executed to remediate each area of concern. The final phase of groundwater clean-up and monitoring at Louisiana Station is expected to continue for several more years. Future costs are not expected to exceed Entergy Gulf States Louisiana’s existing provision of $0.7 million.

Entergy Louisiana and Entergy New Orleans

Several class action and other suits have been filed in state and federal courts seeking relief from Entergy Louisiana and Entergy New Orleans and others for damages caused by the disposal of hazardous waste and for asbestos-related disease allegedly resulting from exposure on Entergy Louisiana’s and Entergy New Orleans’s premises (see “Litigation” below).

During 1993, the LDEQ issued new rules for solid waste regulation, including regulation of wastewater impoundments. Entergy Louisiana has determined that some of its power plant wastewater impoundments were affected by these regulations and may require remediation, repair, or closure. Completion of this work is dependent on pending LDEQ approval of submitted solid waste permit applications. As a result, a recorded liability in the amount of $1.9 million for Entergy Louisiana existed at December 31, 2011 for ongoing wastewater remediation and repairs and closures. Management believes this reserve to be adequate based on current estimates.

Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy New Orleans, and Entergy Texas

The Texas Commission on Environmental Quality (TCEQ) notified Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy New Orleans, and Entergy Texas that the TCEQ believes those entities are PRPs concerning contamination existing at the San Angelo Electric Service Company (SESCO) facility in San Angelo, Texas. The facility operated as a transformer repair and scrapping facility from the 1930s until 2003. Both soil and groundwater contamination exists at the site. Entergy Gulf States, Inc. and Entergy Louisiana sent transformers to this facility during the 1980s. Entergy Gulf States Louisiana, Entergy Texas, Entergy Louisiana, and Entergy Arkansas responded to an information request from the TCEQ and continue to cooperate in this investigation. Entergy Gulf States Louisiana, Entergy Texas, and Entergy Louisiana joined a group of PRPs responding to site conditions in

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cooperation with the State of Texas, creating cost allocation models based on review of SESCO documents and employee interviews, and investigating contribution actions against other PRPs. Entergy Gulf States Louisiana, Entergy Louisiana, and Entergy Texas have agreed to contribute to the remediation of contaminated soil and groundwater at the site in a measure proportionate to those companies’ involvement at the site, while Entergy Arkansas and Entergy New Orleans likely will pay de minimis amounts. Current estimates, although preliminary and variable depending on the level of third-party cost contributions, indicate that Entergy’s total share of remediation costs likely will be less than $1 million. The TCEQ approved an agreed administrative order in September 2006 that allows the implementation of a Remedial Investigation/Feasibility Study at the SESCO site; with the ultimate disposition being a remedial action to remove contaminants of concern. The TCEQ approved the Remedial Investigation Work Plan in May 2007 and field sampling began in July 2007. Off-site removal of certain PCB-impacted soil and debris were completed at the site in December 2010. The Remedial Investigation report was submitted in February 2011 to the TCEQ and was approved on April 15, 2011. The PRP working group prepared a Feasibility Study and description of proposed site remediation and management actions for TCEQ’s review. This information was submitted to the TCEQ in June 2011.

Entergy Mississippi, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy New Orleans, and Entergy Texas

The EPA notified Entergy Mississippi, Entergy Gulf States Louisiana, Entergy Texas, and Entergy New Orleans that the EPA believes those entities are PRPs concerning contamination of an area known as “Devil’s Swamp Lake” near the Port of Baton Rouge, Louisiana. The area allegedly was contaminated by the operations of Rollins Environmental (LA), Inc, which operated a disposal facility to which many companies contributed waste. Documents provided by the EPA indicate that Entergy Louisiana may also be a PRP. Entergy continues to monitor this developing situation.

Entergy

In November 2010 a transformer at the Indian Point facility failed, resulting in a fire and the release of non-PCB oil to the ground surface. The fire was extinguished by the facility’s fire deluge system. No injuries occurred due to the transformer failure or company response. Non-PCB oil and deluge water were released into the facility’s discharge canal and the environment surrounding the transformer and discharge canal, including the Hudson River, as a result of the failure, fire, and fire suppression. Once the fire was extinguished, Indian Point personnel and contractors began recovering the oil from the damaged transformer, the transformer containment moat, and the area surrounding the transformer. The State of New York has indicated its intention to assess a penalty due to the release of oil to waters of the state and the failure of the transformer containment moat to prevent this release of oil. Discussions with the state continue.

Litigation

Entergy uses legal and appropriate means to contest litigation threatened or filed against it, but certain states in which Entergy operates have proven to be unusually litigious environments. Judges and juries in Louisiana, Mississippi, and Texas have demonstrated a willingness to grant large verdicts, including punitive damages, to plaintiffs in personal injury, property damage, and business tort cases. The litigation environment in these states poses a significant business risk to Entergy.

Ratepayer and Fuel Cost Recovery Lawsuits (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas)

Texas Power Price Lawsuit

In August 2003, a lawsuit was filed in the district court of Chambers County, Texas by Texas residents on behalf of a purported class apparently of the Texas retail customers of Entergy Gulf States, Inc. who were billed and paid for electric power from January 1, 1994 to the present. The named defendants include Entergy Corporation, Entergy Services, Entergy Power, Entergy Power Marketing Corp., and Entergy Arkansas. Entergy Gulf States, Inc. was not a named defendant, but is alleged to be a co-conspirator. The court granted the request of Entergy Gulf States, Inc. to intervene in the lawsuit to protect its interests.

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Plaintiffs allege that the defendants implemented a “price gouging accounting scheme” to sell to plaintiffs and similarly situated utility customers higher priced power generated by the defendants while rejecting and/or reselling to off-system utilities less expensive power offered and/or purchased from off-system suppliers and/or generated by the Entergy system. In particular, plaintiffs allege that the defendants manipulated and continue to manipulate the dispatch of generation so that power is purchased from affiliated expensive resources instead of buying cheaper off-system power.

Plaintiffs stated in their pleadings that customers in Texas were charged at least $57 million above prevailing market prices for power. Plaintiffs seek actual, consequential and exemplary damages, costs and attorneys’ fees, and disgorgement of profits. The plaintiffs’ experts have tendered a report calculating damages in a large range, from $153 million to $972 million in present value, under various scenarios. The Entergy defendants have tendered expert reports challenging the assumptions, methodologies, and conclusions of the plaintiffs’ expert reports.

The case is pending in state district court, and a class certification hearing was held in August 2011. The decision of the court on class certification is pending.

Mississippi Attorney General Complaint

The Mississippi attorney general filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. The litigation is wide ranging and relates to tariffs and procedures under which Entergy Mississippi purchases power not generated in Mississippi to meet electricity demand. Entergy believes the complaint is unfounded. On December 29, 2008, the defendant Entergy companies filed to remove the attorney general’s suit to U.S. District Court (the forum that Entergy believes is appropriate to resolve the types of federal issues raised in the suit), where it is currently pending, and additionally answered the complaint and filed a counter-claim for relief based upon the Mississippi Public Utilities Act and the Federal Power Act. The Mississippi attorney general has filed a pleading seeking to remand the matter to state court. In May 2009, the defendant Entergy companies filed a motion for judgment on the pleadings asserting grounds of federal preemption, the exclusive jurisdiction of the MPSC, and factual errors in the attorney general’s complaint.

Fiber Optic Cable Litigation (Entergy Corporation and Entergy Louisiana)

Several property owners have filed a class action suit against Entergy Louisiana, Entergy Services, ETHC, and Entergy Technology Company in state court in St. James Parish, Louisiana purportedly on behalf of all property owners in Louisiana who have conveyed easements to the defendants. The lawsuit alleges that Entergy installed fiber optic cable across the plaintiffs’ property without obtaining appropriate easements. The plaintiffs seek damages equal to the fair market value of the surplus fiber optic cable capacity, including a share of the profits made through use of the fiber optic cables, and punitive damages. Entergy removed the case to federal court in New Orleans; however, the district court remanded the case back to state court. In February 2004, the state court entered an order certifying this matter as a class action. Entergy’s appeals of this ruling were denied. The parties have entered into a term sheet establishing basic terms for a settlement that must be approved by the court.

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Asbestos Litigation (Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas)

Numerous lawsuits have been filed in federal and state courts primarily in Texas and Louisiana, primarily by contractor employees who worked in the 1940-1980s timeframe, against Entergy Gulf States Louisiana and Entergy Texas, and to a lesser extent the other Utility operating companies, as premises owners of power plants, for damages caused by alleged exposure to asbestos. Many other defendants are named in these lawsuits as well. Currently, there are approximately 500 lawsuits involving approximately 5,000 claimants. Management believes that adequate provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position or results of operation of the Utility operating companies.

Employment and Labor-related Proceedings (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

The Registrant Subsidiaries and other Entergy subsidiaries are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees. Generally, the amount of damages being sought is not specified in these proceedings. These actions include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board; claims of retaliation; and claims for or regarding benefits under various Entergy Corporation sponsored plans. Entergy and the Registrant Subsidiaries are responding to these suits and proceedings and deny liability to the claimants.

Employees

Employees are an integral part of Entergy’s commitment to serving customers. As of December 31, 2011, Entergy subsidiaries employed 14,682 people.

Utility:
Entergy Arkansas		1,357
Entergy Gulf States Louisiana		805
Entergy Louisiana		937
Entergy Mississippi		736
Entergy New Orleans		342
Entergy Texas		674
System Energy		-
Entergy Operations		2,867
Entergy Services		3,138
Entergy Nuclear Operations		3,709
Other subsidiaries		117
Total Entergy		14,682

Approximately 5,300 employees are represented by the International Brotherhood of Electrical Workers, the Utility Workers Union of America, the International Brotherhood of Teamsters, the United Government Security Officers of America, and the International Union, Security, Police, Fire Professionals of America.

Availability of SEC filings and other information on Entergy’s website

Entergy electronically files reports with the SEC, including annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, proxies, and amendments to such reports. The public may read and copy any materials that Entergy files with the SEC at the SEC’s Public Reference Room at 100 F Street, NE, Washington, D.C. 20549. The public may obtain information on the operation of the Public Reference Room by calling the SEC at 1-800-SEC-0330. The SEC also maintains an internet site that contains reports, proxy and information statements, and other information regarding registrants that file electronically with the SEC at http://www.sec.gov.

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Entergy uses its website, http://www.entergy.com, as a routine channel for distribution of important information, including news releases, analyst presentations and financial information. Filings made with the SEC are posted and available without charge on Entergy's website as soon as reasonably practicable after they are electronically filed with, or furnished to, the SEC. These filings include our annual and quarterly reports on Forms 10-K and 10-Q (including related filings in XBRL format) and current reports on Form 8-K; our proxy statements; and any amendments to those reports or statements. All such postings and filings are available on Entergy's Investor Relations website free of charge. Entergy is providing the address to its Internet site solely for the information of investors and does not intend the address to be an active link or to otherwise incorporate the contents of the website into this report.

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RISK FACTORS

Investors should review carefully the following risk factors and the other information in this Form 10-K. The risks that Entergy faces are not limited to those in this section. There may be additional risks and uncertainties (either currently unknown or not currently believed to be material) that could adversely affect Entergy's financial condition, results of operations and liquidity. See "FORWARD-LOOKING INFORMATION."

Utility Regulatory Risks

(Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas and System Energy)

The terms and conditions of service, including electric and gas rates, of the Utility operating companies and System Energy are determined through regulatory approval proceedings that are lengthy and subject to appeal that could result in delays in effecting rate changes and uncertainty as to ultimate results.

The rates that the Utility operating companies and System Energy charge reflect their capital expenditures, operations and maintenance charges, allowed rates of return, financing costs, and related costs of service. These rates significantly influence the financial condition, results of operations, and liquidity of Entergy and each of the Utility operating companies and System Energy. These rates are determined in regulatory proceedings and are subject to periodic regulatory review and adjustment.

In addition, regulators can initiate proceedings to investigate the prudence of costs in the Utility operating companies' base rates and examine, among other things, the reasonableness or prudence of the companies' operation and maintenance practices, level of expenditures (including storm costs), allowed rates of return and rate base, proposed resource acquisitions and previously incurred capital expenditures. The regulators can disallow costs found not to have been prudently incurred or found not to have been incurred in compliance with applicable tariffs, creating some risk to the ultimate recovery of those costs. Regulatory proceedings relating to rates and other matters typically involve multiple parties seeking to limit or reduce rates. The proceedings generally have long timelines, are primarily based on historical costs, and may or may not be limited by statute, which could cause the Utility operating companies and System Energy to experience regulatory lag in recovering such costs through rates. Decisions are typically subject to appeal, potentially leading to additional uncertainty associated with rate case proceedings. Although four of the Utility operating companies (Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi and Entergy New Orleans) currently obtain recovery under formula rate plans, at some point in the future these formula rate plans may no longer be extended, at which time these Utility operating companies would operate again in a more traditional rate case environment. In addition, Entergy Gulf States Louisiana and Entergy Louisiana were required by the LPSC to file full rate cases by January 2013 when their current formula rate plans expire.

The Utility operating companies and System Energy, and the energy industry as a whole, have experienced a period of rising costs and investments, which could result in more frequent rate cases and requests for, and the continuation of, cost recovery mechanisms. For information regarding rate case proceedings and formula rate plans applicable to certain of the Utility operating companies, see Note 2 to the financial statements.

The Utility operating companies recover fuel and purchased power costs through rate mechanisms that are subject to risks of delay or disallowance in regulatory proceedings.

The Utility operating companies recover their fuel and purchased power costs from their customers through rate mechanisms subject to periodic regulatory review and adjustment. Because regulatory review can result in the disallowance of incurred costs found not to have been prudently incurred with the possibility of refunds to ratepayers, there exists some risk to the ultimate recovery of those costs. Regulators can initiate proceedings to investigate the continued usage or the adequacy and operation of the fuel and purchased power recovery clauses of the Utility operating companies.

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The Utility operating companies' cash flows can be negatively affected by the time delays between when gas, power or other commodities are purchased and the ultimate recovery from customers of the costs in rates. On occasion, when the level of incurred costs for fuel and purchased power rises very dramatically, some of the Utility operating companies may agree to defer recovery of a portion of that period's fuel and purchased power costs for recovery at a later date, which could increase the near-term working capital and borrowing requirements of those companies. For a description of fuel and purchased power recovery mechanisms and information regarding the regulatory proceedings for fuel and purchased power recovery, see Note 2 to the financial statements.

As a result of a challenge by the LPSC, the manner in which the Utility operating companies have traditionally shared the costs associated with coordinated planning, construction and operation of generating resources has been changed by the FERC, which will require adjustment of retail and wholesale rates in the jurisdictions where the Utility operating companies provide service and has introduced additional uncertainty in the ratemaking process.

The Utility operating companies historically have engaged in the coordinated planning, construction, and operation of generating resources and bulk transmission facilities under the terms of the System Agreement, which is a rate schedule that has been approved by the FERC. In 2005, the FERC issued a decision requiring changes to the cost allocation methodology used in that rate schedule.

In 2007 through 2011, payments were made by Entergy Arkansas to certain of the Utility operating companies in compliance with the 2005 FERC decision on the cost allocation methodology. There have been challenges to the level of payments made by Entergy Arkansas under the FERC’s decision and the prudence of the Utility operating companies’ production costs. The ability to recover in rates any changes to the cost allocation resulting from the challenges, and timing of such recovery, could be uncertain and could be the subject of additional regulatory and other proceedings. For information regarding these and other proceedings associated with the System Agreement, as well as additional information regarding the System Agreement itself, see Note 2 to financial statements, System Agreement Cost Equalization Proceedings. The outcome and timing of this FERC proceeding and resulting recovery and impact on rates cannot be predicted at this time.

There is uncertainty as to the timing or form of any successor arrangement to the System Agreement and the effect of such arrangement (or absence thereof) on Entergy and the Utility operating companies.

Based upon the effect of the FERC decision described in the preceding risk factor, in December 2005, Entergy Arkansas provided notice of its intent to terminate its participation in the System Agreement. In November 2007, Entergy Mississippi provided its notice to terminate its participation in the System Agreement. Each notice of termination is effective ninety-six (96) months from the date of notice (December 2013 for Entergy Arkansas and November 2015 for Entergy Mississippi) or such earlier date as authorized by the FERC. The FERC accepted the notices in November 2009; the LPSC and City Council have requested rehearing of that order. In February 2011, the FERC denied the request for rehearing. The LPSC has appealed the FERC’s decision to the U.S. Court of Appeals for the District of Columbia and oral argument was held January 13, 2012.

The Utility operating companies have concluded that joining the MISO RTO is in the best interest of all stakeholders and are seeking regulatory approvals to accomplish the transfer of functional control of their transmission assets to the MISO RTO by December 2013. However, Entergy cannot predict when or whether it will obtain the approvals necessary to join the MISO RTO, when the Utility operating companies’ generation and transmission systems can be fully integrated into the MISO RTO, or whether alternative arrangements will need to be implemented to allow Entergy Arkansas, and eventually Entergy Mississippi, to operate independent of the System Agreement, and the effect such arrangements (or the absence thereof) will have on Entergy or the Utility operating companies.

For further information regarding the FERC and APSC proceedings relating to the System Agreement, see “Rate, Cost-recovery, and Other Regulation – Federal Regulation – System Agreement” section of Management’s Financial Discussion and Analysis for Entergy Corporation and Subsidiaries.

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The arrangement for the operation of the Utility operating companies’ transmission system faces regulatory and operating challenges and uncertainty in connection with the Utility operating companies’ proposal to move to the MISO RTO and the scheduled expiration of the current Independent Coordinator of Transmission arrangement in November 2012.

In 2000, the FERC issued an order encouraging utilities to voluntarily place their transmission facilities under the control of an independent RTO. In November 2006, the Utility operating companies installed the Southwest Power Pool (SPP), a regional transmission organization, as their Independent Coordinator of Transmission (ICT) with responsibility for certain transmission tariff functions, including granting or denying transmission service, administering OASIS, evaluating all transmission requests, and serving as the reliability coordinator. The initial term of the ICT was for four years and in November 2010 the FERC approved an extension of the ICT arrangement for two years, or until November 2012. In its order issued in March 2009 pertaining to a requested modification regarding the weekly procurement process (WPP) through the ICT arrangement, the FERC imposed conditions related to the ICT arrangement and indicated it wanted an evaluation of the success of the ICT arrangement and transmission access on the Entergy transmission system. In compliance with the FERC’s March 2009 order, the Utility operating companies filed with the FERC a process for evaluating the modification or replacement of the current ICT arrangement. An Entergy Regional State Committee (E-RSC), comprised of one representative from each of the Utility operating companies’ retail regulators has been formed and, in concert with the FERC, retained an independent entity to conduct a cost/benefit analysis of comparing the ICT arrangement to a proposal under which Entergy would join the SPP RTO. The scope of the study was expanded to consider Entergy joining the MISO RTO as another alternative. On April 25, 2011, Entergy announced that each of the Utility operating companies propose joining the MISO RTO. In May 2011, the Utility operating companies submitted to each of their respective retail regulators the cost-benefit analysis comparing the ICT arrangement to joining the SPP RTO or the MISO RTO. The Utility operating companies either have filed or expect to file in 2012 applications with their local regulators seeking to join the MISO RTO and transfer control of the companies’ transmission assets to the MISO RTO. The target implementation date for joining the MISO RTO is December 2013. For further information regarding the FERC and proceedings related to the ICT and MISO, see “Rate, Cost-recovery, and Other Regulation - Federal Regulation - Independent Coordinator of Transmission” section of Management’s Financial Discussion and Analysis for Entergy Corporation and Subsidiaries.

There is uncertainty as to whether the Utility operating companies’ proposal to join the MISO RTO by December 2013 will receive all required regulatory approvals in a timely manner and, if the proposal is approved, the nature and effect of any operational challenges the Utility operating companies might face in connection with integration into the MISO RTO. For the period of time prior to integration of all of the Utility operating companies into the MISO RTO or in the event all necessary approvals to participate in the MISO RTO are not obtained in a timely manner, an extension of the current ICT arrangement or the establishment of a similar arrangement with another qualified entity may be required. The outcome of any effort to negotiate an extension of the current arrangement or to make alternative arrangements cannot be predicted at this time.

(Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas)

A delay or failure in recovering amounts for storm restoration costs incurred as a result of severe weather could have material effects on Entergy and those Utility operating companies affected by severe weather.

Entergy's and its Utility operating companies' results of operations, liquidity and financial condition can be materially affected by the destructive effects of severe weather. Severe weather can also result in significant outages for the customers of the Utility operating companies and, therefore, reduced revenues for the Utility operating companies during the period of the outages. A delay or failure in recovering amounts for storm restoration costs incurred or revenues lost as a result of severe weather could have a material effect on Entergy and those Utility operating companies affected by severe weather.

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Nuclear Operating and Regulatory Risks

(Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy)

Certain of the Utility operating companies, System Energy, and Entergy Wholesale Commodities must consistently operate their nuclear power plants at high capacity factors in order to be successful, and lower capacity factors could materially affect Entergy's and their results of operations, financial condition and liquidity.

Nuclear capacity factors significantly affect the results of operations of certain Utility operating companies, System Energy and Entergy Wholesale Commodities. Nuclear plant operations involve substantial fixed operating costs. Consequently, to be successful, a plant owner must consistently operate its nuclear power plants at high capacity factors. For the Utility operating companies that own nuclear plants, lower capacity factors can increase production costs by requiring the affected companies to generate additional energy, sometimes at higher costs, from their fossil facilities or purchase additional energy in the spot or forward markets in order to satisfy their supply needs. For the Entergy Wholesale Commodities nuclear plants, lower capacity factors directly affect revenues and cash flow from operations. Although most of the Entergy Wholesale Commodities nuclear forward sales are on a pure unit-contingent basis, which depends on the availability of the asset, some of the unit-contingent contracts guarantee a specified minimum capacity factor. In the event these plants were operating below the guaranteed capacity factors, Entergy would be subject to price risk for the undelivered power. Entergy Wholesale Commodities’ nuclear forward sales contracts can also be on a firm LD basis, which subjects Entergy to increasing price risk if capacity factors decrease.

Certain of the Utility operating companies, System Energy, and Entergy Wholesale Commodities’ nuclear plant owners periodically shut down their nuclear power plants to replenish fuel. Plant maintenance and upgrades are often scheduled during such refueling outages. If refueling outages last longer than anticipated or if unplanned outages arise, Entergy's and their results of operations, financial condition and liquidity could be materially affected.

Outages at nuclear power plants to replenish fuel require the plant to be “turned off.” Refueling outages generally are planned to occur once every 18 to 24 months and average approximately 30 days in duration. Plant maintenance and upgrades are often scheduled during such planned outages. When refueling outages last longer than anticipated or a plant experiences unplanned outages, capacity factors decrease and maintenance costs may increase. Entergy Wholesale Commodities’ nuclear plants may face lower margins due to higher costs and lower energy sales for unit-contingent power supply contracts or potentially higher energy replacement costs for unit-contingent contracts with capacity guarantees that are not met due to extended or unplanned outages.

Certain of the Utility operating companies, System Energy, and Entergy Wholesale Commodities face risks related to the purchase of uranium fuel (and its conversion, enrichment and fabrication), and the risk of being unable to effectively manage these risks by purchasing from a diversified mix of sellers located in a diversified mix of countries could materially affect Entergy's and their results of operations, financial condition and liquidity.

Based upon currently planned fuel cycles, Entergy's nuclear units have a diversified portfolio of contracts and inventory that provides substantially adequate nuclear fuel materials and conversion and enrichment services at what Entergy believes are reasonably predictable prices through most of 2012, and with substantial additional amounts after that time. Entergy's ability to purchase nuclear fuel at reasonably predictable prices, however, depends upon the performance reliability of uranium miners. There are a number of possible alternate suppliers that may be accessed to mitigate any supplier performance failure, although the pricing of any such alternate uranium supply from the market will be dependent upon the market for uranium supply at that time. Entergy also may draw upon its own inventory intended for later generation periods, depending upon its risk management strategy at that time. Entergy

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buys uranium from a diversified mix of sellers located in a diversified mix of countries, and from time to time purchases from nearly all qualified reliable major market participants worldwide that sell into the U.S. Market prices for nuclear fuel have been extremely volatile from time to time in the past. Although Entergy’s nuclear fuel contract portfolio provides a degree of hedging against market risks for several years, costs for nuclear fuel in the future cannot be predicted with certainty due to normal inherent market uncertainties, and price increases could materially affect the liquidity, financial condition and results of operations of certain of the Utility operating companies, System Energy, and Entergy Wholesale Commodities.

Certain of the Utility operating companies, System Energy, and the Entergy Wholesale Commodities business face the risk that the NRC will change or modify its regulations or suspend or revoke their licenses, which could materially affect Entergy's and their results of operations, financial condition and liquidity.

Under the Atomic Energy Act and Energy Reorganization Act, the NRC regulates the operation of nuclear power plants. The NRC may modify, suspend or revoke licenses, shut down a nuclear facility and impose civil penalties for failure to comply with the Atomic Energy Act, related regulations or the terms of the licenses for nuclear facilities. A change in the Atomic Energy Act, other applicable statutes, or the applicable regulations or licenses may require a substantial increase in capital expenditures or may result in increased operating or decommissioning costs and could materially affect the results of operations, liquidity or financial condition of Entergy (through Entergy Wholesale Commodities), its Utility operating companies or System Energy. Events at nuclear plants owned by others, as well as those owned by one of these companies, may cause the NRC to initiate such actions. As a result, if an incident were to occur at any nuclear generating unit, whether an Entergy nuclear generating unit or not, it could materially affect the financial condition, results of operations and liquidity of Entergy, certain of the Utility operating companies, System Energy or Entergy Wholesale Commodities. For example, the earthquake of March 11, 2011 that affected the Fukushima Daiichi nuclear plants in Japan is expected to result in regulatory changes in the U.S. that may impose additional costs on all U.S. nuclear plants, some of which could be material.

Certain of the Utility operating companies, System Energy, and Entergy Wholesale Commodities are exposed to risks and costs related to operating and maintaining their nuclear power plants, and their failure to maintain operational efficiency at their nuclear power plants could materially affect Entergy's and their results of operations, financial condition and liquidity.

The nuclear generating units owned by certain of the Utility operating companies, System Energy, and the Entergy Wholesale Commodities business began commercial operations in the 1970s-1980s. Older equipment may require more capital expenditures to keep each of these nuclear power plants operating efficiently. This equipment is also likely to require periodic upgrading and improvement. Any unexpected failure, including failure associated with breakdowns, forced outages or any unanticipated capital expenditures, could result in reduced profitability. Operations at any of the nuclear generating units owned and operated by Entergy's subsidiaries could degrade to the point where the affected unit needs to be shut down or operated at less than full capacity. If this were to happen, identifying and correcting the causes may require significant time and expense. A decision may be made to close a unit rather than incur the expense of restarting it or returning the unit to full capacity. For Entergy Wholesale Commodities, this could result in lost revenue and increased fuel and purchased power expense to meet supply commitments and penalties for failure to perform under their contracts with customers. Moreover, Entergy is becoming more dependent on fewer suppliers for key parts of Entergy's nuclear power plants that may need to be replaced or refurbished. This dependence on a reduced number of suppliers could result in delays in obtaining qualified replacement parts and, therefore, greater expense for Entergy.

The costs associated with the storage of the spent nuclear fuel of certain of the Utility operating companies, System Energy and the owners of the Entergy Wholesale Commodities nuclear power plants, as well as the costs of and their ability to fully decommission their nuclear power plants, could be significantly affected by the timing of the opening of a spent nuclear fuel storage facility, as well as interim storage and transportation requirements.

Certain of the Utility operating companies, System Energy and the owners of the Entergy Wholesale Commodities nuclear plants incur costs on a periodic basis for the on-site storage of spent nuclear fuel. The approval of a license for a national repository for the storage of spent nuclear fuel, such as the one proposed for Yucca Mountain, Nevada, or any interim storage facility, and the timing of such facility opening, will significantly affect the costs

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associated with storage of spent nuclear fuel. For example, while the DOE is required by law to proceed with the licensing of Yucca Mountain and, after the license is granted by the NRC, to construct the repository and commence the receipt of spent fuel, the Obama administration has expressed its intention and taken specific steps to discontinue the Yucca Mountain project and study a new spent fuel strategy. These actions may prolong the time before spent fuel is removed from Entergy’s plant sites. Because the DOE has not accomplished its objectives, it is in non-compliance with the Nuclear Waste Policy Act of 1982 and has breached its spent fuel disposal contracts, and Entergy has sued the DOE for such breach. Furthermore, Entergy is uncertain as to when the DOE plans to commence acceptance of spent fuel from its facilities for storage or disposal. As a result, continuing future expenditures will be required to increase spent fuel storage capacity at the companies’ nuclear sites. The costs of on-site storage are also affected by regulatory requirements for such storage. In addition, the availability of a repository or other off-site storage facility for spent nuclear fuel may affect the ability to fully decommission the nuclear units and the costs relating to decommissioning. For further information regarding spent fuel storage, see the "Critical Accounting Estimates – Nuclear Decommissioning Costs – Spent Fuel Disposal” section of Management's Financial Discussion and Analysis for Entergy, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy.

Certain of the Utility operating companies, System Energy, and the Entergy Wholesale Commodities nuclear plant owners may be required to pay substantial retrospective premiums imposed under the Price-Anderson Act in the event of a nuclear incident, and losses not covered by insurance could have a material effect on Entergy's and their results of operations, financial condition or liquidity.

Accidents and other unforeseen problems at nuclear power plants have occurred both in the United States and elsewhere. The Price-Anderson Act limits each reactor owner's public liability (off-site) for a single nuclear incident to the payment of retrospective premiums into a secondary insurance pool of up to approximately $117.5 million per reactor. With 104 reactors currently participating, this translates to a total public liability cap of approximately $12.2 billion per incident. The limit is subject to change to account for the effects of inflation, a change in the primary limit of insurance coverage, and changes in the number of licensed reactors. As required by the Price-Anderson Act, the Utility operating companies, System Energy, and Entergy Wholesale Commodities carry the maximum available amount of primary nuclear off-site liability insurance with American Nuclear Insurers (currently $375 million for each operating site). Claims for any nuclear incident exceeding that amount are covered under the retrospective premiums paid into the secondary insurance pool. As a result, in the event of a nuclear incident that causes damages (off-site) in excess of the $375 million in primary insurance coverage, each owner of a nuclear plant reactor, including Entergy's Utility operating companies, System Energy, and the Entergy Wholesale Commodities plant owners, regardless of fault or proximity to the incident, will be required to pay a retrospective premium, equal to its proportionate share of the loss in excess of the $375 million primary level, up to a maximum of $117.5 million per reactor per incident (Entergy's maximum total contingent obligation per incident is $1.3 billion). The retrospective premium payment is currently limited to $17.5 million per year per incident per reactor until the aggregate public liability for each licensee is paid up to the $117.5 million cap.

NEIL is a utility industry mutual insurance company, owned by its members. All member plants could be subject to assessments (retrospective premium of up to 10 times current annual premium for all policies) should the surplus (reserve) be significantly depleted due to insured losses. As of April 1, 2011, the maximum assessment amounts total $72.7 million for the Utility plants and $89.3 million for the Entergy Wholesale Commodities plants. Retrospective Premium Insurance available through NEIL’s reinsurance treaty can cover the potential assessments. The Entergy Wholesale Commodities plants currently maintain the Retrospective Premium Insurance to cover this potential assessment.

As an owner of nuclear power plants, Entergy participates in industry self-insurance programs and could be liable to fund claims should a plant owned by a different company experience a major event. Any resulting liability from a nuclear accident may exceed the applicable primary insurance coverage and require contribution of additional funds through the industry-wide program that could significantly affect the results of operations, financial condition or liquidity of Entergy, certain of the Utility operating companies, System Energy or the Entergy Wholesale Commodities subsidiaries.

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Market performance and other changes may decrease the value of assets in the decommissioning trusts, which then could require significant additional funding.

Owners of nuclear generating plants have an obligation to decommission those plants. Certain of the Utility operating companies, System Energy and owners of the Entergy Wholesale Commodities nuclear power plants maintain decommissioning trust funds for this purpose. Certain of the Utility operating companies collect funds from their customers, which are deposited into the trusts covering the units operated for or on behalf of those companies. Those rate collections are based upon operating license lives as well as estimated trust fund earnings and decommissioning costs. In connection with the acquisition of certain nuclear plants, the Entergy Wholesale Commodities plant owners also acquired decommissioning trust funds that are funded in accordance with NRC regulations. Assets in these trust funds are subject to market fluctuations, will yield uncertain returns that may fall below projected return rates, and may result in losses resulting from the recognition of impairments of the value of certain securities held in these trust funds. As part of the Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades/Big Rock Point purchases, the former owners transferred decommissioning trust funds, along with the liability to decommission the plants, to the respective Entergy Wholesale Commodities nuclear power plant owners. In addition, the former owner of Indian Point 3 and FitzPatrick retained the decommissioning trusts and related liability to decommission these plants, but has the right to require the respective Entergy Wholesale Commodities nuclear plant owners to assume the decommissioning liability provided that it assigns the funds in the corresponding decommissioning trust, up to a specified level, to such owners. Alternatively, the former owner may contract with Entergy Nuclear, Inc. for the decommissioning work at a price equal to the transferred funds mentioned above. As part of the Indian Point 1 and 2 purchase, the Entergy Wholesale Commodities nuclear power plant owner also funded an additional $25 million to a supplemental decommissioning trust fund. As part of the Palisades transaction, the Entergy Wholesale Commodities business assumed responsibility for spent fuel at the decommissioned Big Rock Point nuclear plant, which is located near Charlevoix, Michigan. Once the spent fuel is removed from the site, the Entergy Wholesale Commodities business will dismantle the spent fuel storage facility and complete site decommissioning. The Entergy Wholesale Commodities business expects to fund this activity from operating revenue, and Entergy is providing $5 million in credit support to provide financial assurance to the NRC for this obligation.

In 2008, Entergy experienced declines in the market value of assets held in the trust funds for meeting its decommissioning funding assurance obligations for its plants. This decline adversely affected Entergy’s ability to demonstrate compliance with the NRC’s requirements for providing financial assurance for decommissioning funding for some of its plants, which deficiencies have now been corrected. An early plant shutdown, poor investment results or higher than anticipated decommissioning costs could cause trust fund assets to be insufficient to meet the decommissioning obligations, with the result that the Entergy Wholesale Commodities nuclear plant owners may be required to provide additional funds or credit support to satisfy regulatory requirements for decommissioning. For further information regarding nuclear decommissioning costs, see the "Critical Accounting Estimates – Nuclear Decommissioning Costs" section of Management's Financial Discussion and Analysis for Entergy, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy and Note 9 to the financial statements.

New or existing safety concerns regarding operating nuclear power plants and nuclear fuel could lead to restrictions upon the operation of Entergy’s nuclear power plants.

New and existing concerns are being expressed in public forums about the safety of nuclear generating units and nuclear fuel, in particular in the northeastern United States, which is where five of the six units in the current fleet of Entergy Wholesale Commodities nuclear power plants are located. These concerns have led to, and are expected to continue to lead to, various proposals to Federal regulators and governing bodies in some localities where Entergy's subsidiaries own nuclear generating units for legislative and regulatory changes that could lead to the shutdown of nuclear units, denial of license renewal applications, municipalization of nuclear units, restrictions on nuclear units as a result of unavailability of sites for spent nuclear fuel storage and disposal, or other adverse effects on owning and operating nuclear generating units. Entergy vigorously responds to these concerns and proposals. If any of the existing proposals, or any proposals that may arise in the future with respect to legislative and regulatory changes, become effective, they could have a material effect on Entergy's results of operations, financial condition and liquidity.

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(Entergy Corporation)

A failure to obtain renewed licenses for the continued operation of the Entergy Wholesale Commodities nuclear power plants could have a material effect on Entergy's results of operations, financial condition, and liquidity and could lead to an increase in depreciation rates or an acceleration of the timing for the funding of decommissioning obligations.

The license renewal and related processes for the Entergy Wholesale Commodities nuclear power plants have been and may continue to be the subject of significant public debate and regulatory and legislative review and scrutiny at the federal and, in certain cases, state level. The operating licenses for Pilgrim, Indian Point 2 and Indian Point 3 expire in June 2012, September 2013 and December 2015, respectively. Because these plants filed timely license renewal applications, the NRC’s rules provide that these plants may continue to operate under their existing operating licenses until their renewal applications have been finally determined. Various parties have expressed opposition to renewal of these licenses. Renewal of the Indian Point licenses is the subject of ongoing proceedings before the Atomic Safety and Licensing Board (ASLB) of the NRC. Initial hearings on certain of the contentions admitted by the ASLB currently are expected to begin by the end of 2012. In the Pilgrim license renewal proceeding, the ASLB has denied the last pending proposed contention and has terminated proceedings before it. Appeals of ASLB decisions remain pending before the NRC. Also pending before the NRC is a motion by Entergy affiliates requesting specific authorization to NRC staff to issue the Pilgrim license. In responding to that motion, NRC staff stated the position that whether to issue a license where no admitted contentions are pending is a matter of staff discretion. There is no schedule for NRC action on the pending appeals or motion.

In relation to Indian Point 2 and Indian Point 3, the New York State Department of Environmental Conservation has taken the position that these plant owners must obtain a new state-issued Clean Water Act Section 401 water quality certification as part of the license renewal process. For the Indian Point plants, the Entergy Wholesale Commodities plant owners also must ensure that requirements of the Coastal Zone Management Act, which is administered in New York State primarily by the New York Department of State, are satisfied prior to getting the renewed licenses. For further information regarding these environmental regulations see “Environmental Regulation, Clean Water Act” in Part I, Item 1.

The NRC operating license for Vermont Yankee was to expire in March 2012. In March 2011 the NRC renewed Vermont Yankee’s operating license for an additional 20 years, as a result of which the license now expires in 2032. Vermont Yankee also is operating under a Certificate of Public Good from the State of Vermont that expires in March 2012, but has an application pending before the Vermont Public Service Board for a new Certificate of Public Good for operation until March 2032. For additional discussion regarding the continued operation of the Vermont Yankee plant, see “Impairment of Long-Lived Assets” in Note 1 to the financial statements.

If the NRC finally denies the applications for the renewal of operating licenses for one or more of the Entergy Wholesale Commodities nuclear power plants, or a state in which any such nuclear power plant is located is able to prevent the continued operation of such plant, Entergy’s results of operations, financial condition, and liquidity could be materially affected by loss of revenue and cash flow associated with the plant or plants, potential impairments of the carrying value of the plants, increased depreciation rates, and an accelerated need for decommissioning funds, which could require additional funding. In addition, Entergy may incur increased operating costs depending on any conditions that may be imposed in connection with license renewal. For further discussion regarding the license renewal processes for the Entergy Wholesale Commodities’ nuclear power plants, see “ENTERGY’S BUSINESS – Entergy Wholesale Commodities – Property – Nuclear Generating Stations” in Part I, Item 1 for Entergy Corporation and its subsidiaries.

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The decommissioning trust fund assets for the nuclear power plants owned by Entergy Wholesale Commodities’ nuclear plant owners may not be adequate to meet decommissioning obligations if one or more of their nuclear power plants is retired earlier than the anticipated shutdown date or if current regulatory requirements change which then could require additional funding.

Under NRC regulations, Entergy’s nuclear subsidiaries are permitted to project the NRC-required decommissioning amount based on an NRC formula or a site-specific estimate, and the amount in each of the Entergy Wholesale Commodities nuclear power plant's decommissioning trusts combined with other decommissioning financial assurances in place. The projections are made based on the operating license expiration date and the mid-point of the subsequent decommissioning process for each of these nuclear power plants. As a result, if the projected amount of our decommissioning trusts exceeds the NRC-required decommissioning amount, then its decommissioning obligations are considered to be funded in accordance with NRC regulations. In the event the projected costs do not sufficiently reflect the actual costs the applicable Entergy subsidiaries would be required to incur to decommission these nuclear power plants, and funding is otherwise inadequate, or if the formula or site-specific estimate is changed to require increased funding, additional resources would be required. Furthermore, depending upon the level of funding available in the trust funds, the NRC may not permit the trust funds to be used to pay for related costs such as the management of spent nuclear fuel that are not included in the formula. The NRC may also require a plan for the provision of separate funding for spent fuel management costs. In addition to NRC requirements, there are other decommissioning-related obligations for certain of the Entergy Wholesale Commodities nuclear power plants, which management believes it will be able to satisfy.

With respect to the decommissioning trusts for Indian Point 2 and Palisades, the total amount in each of those trusts as of December 31, 2011 would not have been sufficient to initiate and complete the immediate near-term radiological decommissioning of the respective unit as of the license termination date of each respective plant, but rather the funds would have been sufficient to place the unit in a condition of safe storage status pending future completion of decommissioning. For example, if an Entergy subsidiary decides to shut down and immediately begin decommissioning one of those nuclear power plants on its license expiration date, its trust funds for the plant as of December 31, 2011 would have been insufficient and the applicable Entergy subsidiary would have been required to rely on other capital resources to fund the remainder of the radiological decommissioning obligations unless the completion of decommissioning could be deferred during some number of years of safe storage status (as is permitted by NRC regulations). If any Entergy subsidiary decides to shut down one of its nuclear power plants earlier than the scheduled shutdown date and conduct a prompt decommissioning, the applicable Entergy subsidiary may be unable to rely upon only the decommissioning trust to fund the entire decommissioning obligations, which would require it to obtain funding from other sources.

Further, federal or state regulatory changes, including mandated increases in decommissioning funding or changes in the methods or standards for decommissioning operations, may also increase the funding requirements of, or accelerate the timing for funding of, the obligations related to the decommissioning of Entergy Wholesale Commodities’ nuclear power plants. As a result, under any of these circumstances, Entergy's results of operations, liquidity and financial condition could be materially affected.

Entergy Wholesale Commodities’ nuclear power plants are exposed to price risk through either advance sale of energy and capacity into forward markets or accepting spot prices primarily in day-ahead markets.

Entergy and its subsidiaries are not guaranteed any rate of return on their capital investments in non-utility businesses. In particular, the sale of capacity and energy from the Entergy Wholesale Commodities nuclear power plants, unless otherwise contracted, is subject to the fluctuation of market power prices. As of December 31, 2011, Entergy Wholesale Commodities nuclear power generation plants had sold forward 88%, 81%, 39%, 25% and 25% of its generation portfolio's planned energy output for 2012, 2013, 2014, 2015, and 2016, respectively. In order to hedge future price risk to desired levels, Entergy Wholesale Commodities utilizes contracts that are unit-contingent and Firm LD and various products such as forward sales, options, and collars.

Market conditions such as product cost, market liquidity and other portfolio considerations influence the product and contractual mix. The obligations under unit-contingent agreements depend on a generating asset that is operating; if the generation asset is not operating, the seller generally is not liable for damages. For some unit-contingent obligations, however, there is also a guarantee of availability that provides for the payment to the power

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purchaser of contract damages, if incurred, in the event the unit owner fails to deliver power as a result of the failure of the specified generation unit to generate power at or above a specified availability threshold. Firm LD sales transactions may be exposed to substantial operational price risk to the extent that the plants do not run as expected and market prices exceed contract prices.

Market prices may fluctuate substantially, sometimes over relatively short periods of time, and at other times experience sustained increases or decreases. Demand for electricity and its fuel stock can fluctuate dramatically, creating periods of substantial under- or over-supply. During periods of over-supply, prices might be depressed. Also, from time to time there may be political pressure, or pressure from regulatory authorities with jurisdiction over wholesale and retail energy commodity and transportation rates, to impose price limitations, credit requirements, bidding rules and other mechanisms to address volatility and other issues in these markets.

The price that different counterparties offer for forward sales is influenced both by market conditions as well as the contract terms such as damage provisions, credit support requirements and the number of available counterparties interested in contracting for the desired forward period. Depending on differences between market factors at the time of contracting versus current conditions, Entergy Wholesale Commodities' contract portfolio may have average contract prices above or below current market prices, including at the expiration of the contracts, which may significantly affect Entergy Wholesale Commodities’ results of operations, financial condition or liquidity. The recent economic downturn and negative trends in the energy commodity markets have resulted in lower natural gas prices, and current prevailing market prices for electricity in the New York and New England power regions are therefore generally below the prices of Entergy Wholesale Commodities’ existing contracts in those regions. To the extent these market conditions persist, Entergy Wholesale Commodities’ realized price per MWh can be expected to continue to decline. See “Entergy Corporation and Subsidiaries, Management’s Financial Discussion and Analysis, Results of Operations, Realized Revenue per MWh for Entergy Wholesale Commodities Nuclear Plants.” With operating licenses for Pilgrim, Indian Point 2 and Indian Point 3 expiring between 2012 and 2015, and as a consequence of any delays in obtaining extension of the operating licenses and any other approvals required for continued operation of the plants, Entergy Wholesale Commodities may enter into fewer unit-contingent forward sales contracts for output from such plants for periods beyond the license expiration.

Among the factors that could affect market prices for electricity and fuel, all of which are beyond Entergy's control to a significant degree, are:

·	prevailing market prices for natural gas, uranium (and its conversion, enrichment and fabrication), coal, oil, and other fuels used in electric generation plants, including associated transportation costs, and supplies of such commodities;

·	seasonality;

·	availability of competitively priced alternative energy sources and the requirements of a renewable portfolio standard;

·	changes in production and storage levels of natural gas, lignite, coal and crude oil and refined products;

·	liquidity in the general wholesale electricity market, including the number of creditworthy counterparties available and interested in entering into forward sales agreements for Entergy’s full hedging term;

·	the actions of external parties, such as the FERC and local independent system operators and other state or Federal energy regulatory bodies, that may impose price limitations and other mechanisms to address some of the volatility in the energy markets;

·	electricity transmission, competing generation or fuel transportation constraints, inoperability or inefficiencies;

·	the general demand for electricity, which may be significantly affected by national and regional economic conditions;

·	weather conditions affecting demand for electricity or availability of hydroelectric power or fuel supplies;

·	the rate of growth in demand for electricity as a result of population changes, regional economic conditions and the implementation of conservation programs;

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·	regulatory policies of state agencies that affect the willingness of Entergy Wholesale Commodities nuclear customers to enter into long-term contracts generally, and contracts for energy in particular;

increases in supplies due to actions of current Entergy Wholesale Commodities nuclear competitors or new market entrants, including the development of new generation facilities, expansion of existing generation facilities, the disaggregation of vertically integrated utilities and improvements in transmission that allow additional supply to reach Entergy Wholesale Commodities’ nuclear markets;

·	union and labor relations;

·	changes in Federal and state energy and environmental laws and regulations and other initiatives, including but not limited to, the price impacts of proposed emission controls such as the Regional Greenhouse Gas Initiative (RGGI);

·	changes in law resulting from federal or state energy legislation or legislation subjecting energy derivatives used in hedging and risk management transactions to governmental regulation; and

·	natural disasters, terrorist actions, wars, embargoes and other catastrophic events.

The Entergy Wholesale Commodities business is subject to substantial governmental regulation and may be adversely affected by legislative, regulatory or market design changes, as well as liability under, or any future inability to comply with, existing or future regulations or requirements.

The Entergy Wholesale Commodities business is subject to extensive federal, state and local laws and regulation. Compliance with the requirements under these various regulatory regimes may cause the Wholesale Commodities business to incur significant additional costs, and failure to comply with such requirements could result in the shutdown of the non-complying facility, the imposition of liens, fines and/or civil or criminal liability.

Public utilities under the Federal Power Act are required to obtain FERC acceptance of their rate schedules for wholesale sales of electricity. Each of the owners of the Entergy Wholesale Commodities nuclear power plants, as well as Entergy Nuclear Power Marketing, LLC, is a "public utility" under the Federal Power Act by virtue of making wholesale sales of electric energy. The FERC has granted these generating and power marketing companies the authority to sell electricity at market-based rates. The FERC’s orders that grant the Entergy Wholesale Commodities’ generating and power marketing companies market-based rate authority reserve the right to revoke or revise that authority if the FERC subsequently determines that the Entergy Wholesale Commodities business can exercise market power in transmission or generation, create barriers to entry, or engage in abusive affiliate transactions. In addition, the Entergy Wholesale Commodities’ market-based sales are subject to certain market behavior rules, and if any of its generating and power marketing companies were deemed to have violated one of those rules, they would be subject to potential disgorgement of profits associated with the violation and/or suspension or revocation of their market-based rate authority and potential penalties of up to $1 million per day per violation. If the Entergy Wholesale Commodities’ generating or power marketing companies were to lose their market-based rate authority, such companies would be required to obtain the FERC’s acceptance of a cost-of-service rate schedule and could become subject to the accounting, record-keeping and reporting requirements that are imposed on utilities with cost-based rate schedules. This could have an adverse effect on the rates the Entergy Wholesale Commodities charges for power from its facilities.

The Entergy Wholesale Commodities business is also affected by legislative and regulatory changes, as well as changes to market design, market rules, tariffs, cost allocations and bidding rules imposed by the existing Independent System Operators. The Independent System Operators that oversee most of the wholesale power markets impose, and in the future may continue to impose, mitigation, including price limitations, offer caps and other mechanisms, to address some of the volatility and the potential exercise of market power in these markets. These types of price limitations and other regulatory mechanisms may have an adverse effect on the profitability of the Entergy Wholesale Commodities business' generation facilities that sell energy and capacity into the wholesale power markets. For further information regarding federal, state and local laws and regulation applicable to the Entergy Wholesale Commodities business, see “Entergy’s Business - Regulation of Entergy’s Business” in Part I, Item 1 for Entergy Corporation and its subsidiaries.

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The regulatory environment applicable to the electric power industry has undergone substantial changes over the past several years as a result of restructuring initiatives at both the state and federal levels. These changes are ongoing and Entergy cannot predict the future design of the wholesale power markets or the ultimate effect that the changing regulatory environment will have on the Entergy Wholesale Commodities business. In addition, in some of these markets, interested parties have proposed material market design changes, including the elimination of a single clearing price mechanism and have raised claims that the competitive marketplace is not working because energy prices in wholesale markets exceed the marginal cost of operating nuclear power plants, as well as proposals to re-regulate the markets, impose a generation tax or require divestitures by generating companies to reduce their market share. Other proposals to re-regulate may be made and legislative or other attention to the electric power market restructuring process may delay or reverse the deregulation process, which could require material changes to business planning models. If competitive restructuring of the electric power markets is reversed, modified, discontinued or delayed, the Entergy Wholesale Commodities business' results of operations, financial condition and liquidity could be materially affected.

The nuclear power plants owned by the Entergy Wholesale Commodities business are subject to impairment charges in certain circumstances, which could have a material effect on Entergy's results of operations, financial condition or liquidity.

Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy over the remaining life of the assets. In particular, the assets of the Entergy Wholesale Commodities business, including the nuclear power plants, are subject to impairment if adverse market conditions arise and continue (such as declines in market prices for electricity), if adverse regulatory events occur (including with respect to environmental regulation), if a unit ceases operation or if a unit's operating license is not renewed. Moreover, the failure of the Entergy Wholesale Commodities business to achieve forecasted operating results and cash flows, an unfavorable change in forecasted operating results or cash flows or a decline in observable industry market multiples could all result in potential impairment charges for the affected assets.

As discussed in Part I, Item 1, Entergy Wholesale Commodities, Property, in this Form 10-K, the operating licenses for Pilgrim, Indian Point 2 and Indian Point 3 expire between 2012 and 2015 and are currently the subject of license renewal processes at the NRC and the states in which the plants operate and the Vermont Yankee plant is the subject of certain state and federal proceedings and federal litigation relating to continued operation of that plant. If Entergy concludes that any of these nuclear power plants is unlikely to operate significantly beyond its current license expiration date, which conclusion would be based on a variety of factors, such a conclusion could result in an impairment of part or all of the carrying value of the plant. Any impairment charge taken by Entergy with respect to its long-lived assets, including the nuclear power plants owned by the Entergy Wholesale Commodities business, would likely be material in the quarter that the charge is taken and could otherwise have a material effect on Entergy's results of operations, financial condition or liquidity.

General Business

(Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas)

Entergy and the Utility operating companies depend on access to the capital markets and, at times, may face potential liquidity constraints, which could make it more difficult to handle future contingencies such as natural disasters or substantial increases in gas and fuel prices. Disruptions in the capital and credit markets may adversely affect Entergy and its subsidiaries' ability to meet liquidity needs, access capital and operate and grow their businesses, and the cost of capital.

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Entergy's business is capital intensive and dependent upon its ability to access capital at reasonable rates and other terms. At times there are also spikes in the price for natural gas and other commodities that increase the liquidity requirements of the Utility operating companies and Entergy Wholesale Commodities. In addition, Entergy's and the Utility operating companies' liquidity needs could significantly increase in the event of a hurricane or other weather-related or unforeseen disaster similar to that experienced in Entergy's service territory with Hurricane Katrina and Hurricane Rita in 2005 and Hurricane Gustav and Hurricane Ike in 2008. The occurrence of one or more contingencies, including a delay in regulatory recovery of fuel or purchased power costs or storm restoration costs, higher than expected pension contributions, an acceleration of payments or decreased credit lines, less cash flow from operations than expected or other unknown events, such as future storms, could cause the financing needs of Entergy and its subsidiaries to increase. In addition, accessing the debt capital markets more frequently in these situations may result in an increase in leverage. Material leverage increases could negatively affect the credit ratings of Entergy and the Utility operating companies, which in turn could negatively affect access to the capital markets.

The global capital and credit markets experienced extreme volatility and disruption in the fourth quarter of 2008 and much of 2009. The inability to raise capital on favorable terms, particularly during times of uncertainty in the capital markets, could negatively affect Entergy and its subsidiaries' ability to maintain and to expand their businesses. Events beyond Entergy's control, such as the volatility and disruption in global capital and credit markets in 2008 and 2009, may create uncertainty that could increase its cost of capital or impair its ability to access the capital markets, including the ability to draw on its bank credit facilities. Entergy and its subsidiaries are unable to predict the degree of success they will have in renewing or replacing their credit facilities as they come up for renewal, including the Entergy Corporation $3.5 billion revolving credit facility that expires in August 2012. Moreover, the size, terms, and covenants of any new credit facilities may not be comparable to, and may be more restrictive than, existing facilities. If Entergy and its subsidiaries are unable to access the credit and capital markets on terms that are reasonable, they may have to delay raising capital, issue shorter-term securities and/or bear an unfavorable cost of capital, which, in turn, could impact their ability to grow their businesses, decrease earnings, significantly reduce financial flexibility and/or limit Entergy Corporation's ability to sustain its current common stock dividend level.

(Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

A downgrade in Entergy Corporation's or its subsidiaries' credit ratings could negatively affect Entergy Corporation's and its subsidiaries' ability to access capital and/or could require Entergy Corporation or its subsidiaries to post collateral, accelerate certain payments or repay certain indebtedness.

There are a number of factors that rating agencies evaluate to arrive at credit ratings for each of Entergy Corporation and the Registrant Subsidiaries, including each Registrant’s regulatory framework, ability to recover costs and earn returns, diversification and financial strength and liquidity. If one or more rating agencies downgrade Entergy Corporation's, any of the Utility operating companies', or System Energy's ratings, particularly below investment grade, borrowing costs would increase, the potential pool of investors and funding sources would likely decrease, and cash or letter of credit collateral demands may be triggered by the terms of a number of commodity contracts, leases and other agreements.

Most of Entergy Corporation's and its subsidiaries' large customers, suppliers and counterparties require sufficient creditworthiness to enter into transactions. If Entergy Corporation's or its subsidiaries' ratings decline, particularly below investment grade, or if certain counterparties believe Entergy Corporation or the Utility operating companies are losing creditworthiness and demand adequate assurance under fuel, gas and purchased power contracts, the counterparties may require posting of collateral in cash or letters of credit, prepayment for fuel, gas or purchased power or accelerated payment, or counterparties may decline business with Entergy Corporation or its subsidiaries. At December 31, 2011, based on power prices at that time, Entergy had liquidity exposure for Entergy Wholesale Commodities business transactions of $133 million under guarantees, $20 million of guarantees that

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support letters of credit, and $6 million of posted cash collateral to the ISOs. As of December 31, 2011 the liquidity exposure associated with Entergy Wholesale Commodities assurance requirements could increase by $132 million for a $1 per MMBtu increase in gas prices in both the short- and long-term markets. In the event of a decrease in Entergy Corporation's credit rating to below investment grade, based on power prices as of December 31, 2011, Entergy would have been required to provide approximately $44 million of additional cash or letters of credit under some of the agreements.

The construction of, and capital improvements to, power generation facilities involve substantial risks. Should construction or capital improvement efforts be unsuccessful, the financial condition, results of operations or liquidity of Entergy and the Utility operating companies could be materially affected.

Entergy's and the Utility operating companies' ability to complete construction of power generation facilities in a timely manner and within budget is contingent upon many variables and subject to substantial risks. These variables include, but are not limited to, project management expertise and escalating costs for materials, labor and environmental compliance. Delays in obtaining permits, shortages in materials and qualified labor, suppliers and contractors not performing as required under their contracts, changes in the scope and timing of projects, poor quality initial cost estimates from contractors, the inability to raise capital on favorable terms, changes in commodity prices affecting revenue, fuel costs, or materials costs, downward changes in the economy, changes in law or regulation, including environmental compliance requirements, and other events beyond the control of the Utility operating companies or the Entergy Wholesale Commodities business may occur that may materially affect the schedule, cost and performance of these projects. If these projects are significantly delayed or become subject to cost overruns or cancellation, Entergy and the Utility operating companies could incur additional costs and termination payments, or face increased risk of potential write-off of the investment in the project. For further information regarding capital expenditure plans and other uses of capital in connection with the potential construction of additional generation supply sources within the Utility operating companies' service territory, and as to the Entergy Wholesale Commodities business, see the "Capital Expenditure Plans and Other Uses of Capital" section of Management's Financial Discussion and Analysis for Entergy and each of the Registrant Subsidiaries.

The Utility operating companies, System Energy and the Entergy Wholesale Commodities business may incur substantial costs to fulfill their obligations related to environmental and other matters.

The businesses in which the Utility operating companies, System Energy and the Entergy Wholesale Commodities business operate are subject to extensive environmental regulation by local, state and Federal authorities. These laws and regulations affect the manner in which the Utility operating companies, System Energy and the Entergy Wholesale Commodities business conduct their operations and make capital expenditures. These laws and regulations also affect how the Utility operating companies, System Energy and the Entergy Wholesale Commodities business manage air emissions, discharges to water, solid and hazardous waste storage and disposal, cooling and service water intake, the protection of threatened and endangered species, hazardous materials transportation, and similar matters. Federal, state, and local authorities continually revise these laws and regulations, and the laws and regulations are subject to judicial interpretation and to the permitting and enforcement discretion vested in the implementing agencies. Developing and implementing plans for facility compliance with these requirements can lead to capital, personnel, and operation and maintenance expenditures. Violations of these requirements can subject the Utility operating companies, System Energy and the Entergy Wholesale Commodities business to enforcement actions, capital expenditures to bring existing facilities into compliance, additional operating costs or operating restrictions to achieve compliance, remediation and clean-up costs, civil penalties, and exposure to third parties' claims for alleged health or property damages or for violations of applicable permits or standards. In addition, the Utility operating companies, System Energy and the Entergy Wholesale Commodities business are subject to liability under these laws for the costs of remediation of environmental contamination of property now or formerly owned or operated by the Utility operating companies, System Energy and the Entergy Wholesale Commodities business and of property contaminated by hazardous substances they generate. The Utility operating companies are currently involved in proceedings relating to sites where hazardous substances have been released and may be subject to additional proceedings in the future. The Utility operating companies, System Energy and the Entergy Wholesale Commodities business have incurred and expect to incur significant costs related to environmental compliance.

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Emissions of nitrogen and sulfur oxides, mercury, particulates, and other regulated air contaminants from generating plants are potentially subject to increased regulation, controls and mitigation expenses. In addition, existing air regulations and programs promulgated by the EPA often are challenged legally, sometimes resulting in large-scale changes to anticipated regulatory regimes and the resulting need to shift course, both operationally and economically, depending on the nature of the changes. Risks relating to global climate change and initiatives to compel CO2 emission reductions are discussed below.

Entergy and its subsidiaries may not be able to obtain or maintain all required environmental regulatory approvals. If there is a delay in obtaining any required environmental regulatory approvals, or if Entergy and its subsidiaries fail to obtain, maintain or comply with any such approval, the operation of its facilities could be stopped or become subject to additional costs. For further information regarding environmental regulation and environmental matters, see the "Regulation of Entergy's Business – Environmental Regulation" section of Part I, Item 1.

The Utility operating companies, System Energy and the Entergy Wholesale Commodities business may incur substantial costs related to reliability standards.

Entergy's business is subject to extensive and mandatory reliability standards. Such standards, which are established by the North American Electric Reliability Corporation (NERC) and the SERC Reliability Corporation (SERC), are approved by the FERC and frequently are reviewed, amended and supplemented. Failure to comply with such standards could result in the imposition of fines or civil penalties, and potential exposure to third party claims for alleged violations of such standards. The standards, as well as the laws and regulations that govern them, are subject to judicial interpretation and to the enforcement discretion vested in the implementing agencies. In addition to exposure to civil penalties and fines, the Utility operating companies have incurred and expect to incur significant costs related to compliance with new and existing reliability standards, including costs associated with the Utility operating companies’ transmission system. The changes to the reliability standards applicable to the electric power industry are ongoing, and Entergy cannot predict the ultimate effect that the reliability standards will have on its Utility and Entergy Wholesale Commodities business. Entergy has notified the SERC of potential violations of certain NERC reliability standards, including certain Critical Infrastructure Protection, Facilities Design, Connection and Maintenance, and System Protection and Control standards. Entergy is working with the SERC to provide information concerning these potential violations. In addition, FERC’s Division of Investigations is conducting an investigation of certain issues relating to the Utility operating companies compliance with certain Reliability Standards related to protective system maintenance, facility ratings and modeling, training, and communications.

(Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas)

The effects of weather and economic conditions and the related impact on electricity and gas usage, may materially affect the Utility operating companies' results of operations.

Temperatures above normal levels in the summer tend to increase summer cooling electricity demand and revenues, and temperatures below moderate levels in the winter tend to increase winter heating electricity and gas demand and revenues. As a corollary, moderate temperatures tend to decrease usage of energy and resulting revenues. Seasonal pricing differentials, coupled with higher consumption levels, typically cause the Utility operating companies to report higher revenues in the third quarter of the fiscal year than in the other quarters. Extreme weather conditions or storms, however, may stress the Utility operating companies' generation facilities and transmission and distribution systems, resulting in increased maintenance and capital costs (and potential increased financing needs), limits on their ability to meet peak customer demand, increased regulatory oversight, and lower customer satisfaction. These extreme conditions could have a material effect on the Utility operating companies' financial condition, results of operations and liquidity.

Industrial sales volume was depressed in the latter part of 2008 and through most of 2009, in part because the overall economy declined, with lower usage across the industrial sector affecting both the large customer industrial segment as well as small and mid-sized industrial customers. It is possible that continued or recurrent poor economic conditions could result in slower or declining sales growth and increased bad debt expense, which could materially affect Entergy's and the Utility operating companies' results of operations, financial condition and liquidity.

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The effects of climate change and environmental and regulatory obligations intended to compel CO2 emission reductions could materially affect the financial condition, results of operations and liquidity of Entergy and the Utility operating companies.

In an effort to address climate change concerns, Federal, state, and local authorities are calling for additional laws and regulations aimed at known or suspected causes of climate change. For example, in response to the United States Supreme Court's 2007 decision holding that the EPA has authority to regulate emissions of CO2 and other "greenhouse gases" under the Clean Air Act, the EPA, various environmental interest groups and other organizations are focusing considerable attention on CO2 emissions from power generation facilities and their potential role in climate change. In 2010, EPA promulgated its first regulations controlling greenhouse gas emissions from certain vehicles and from new and significantly modified stationary sources of emissions, including electric generating units, and additional new source performance standards are expected to be proposed in 2012. Developing and implementing plans for compliance with CO2 emissions reduction requirements can lead to additional capital, personnel, and operation and maintenance expenditures and could significantly affect the economic position of existing facilities and proposed projects; moreover, long term planning to meet environmental requirements can be negatively impacted and costs may increase to the extent laws and regulations change prior to full implementation. Violations of such requirements may subject Entergy and the Utility operating companies to enforcement actions, capital expenditures to bring existing facilities into compliance, additional operating costs or operating restrictions to achieve compliance, civil penalties, and exposure to third parties' claims for alleged health or property damages or for violations of applicable permits or standards. To the extent Entergy believes any of these costs are recoverable in rates, however, additional material rate increases for customers could be resisted by Entergy's regulators and, in extreme cases, Entergy's regulators might deny or defer timely recovery of these costs. Future changes in environmental regulation governing the emission of CO2 and other "greenhouse gases" could make some of Entergy's electric generating units uneconomical to maintain or operate, and could increase the difficulty that Entergy and its subsidiaries have with obtaining or maintaining required environmental regulatory approvals, which could also materially affect the financial condition, results of operations and liquidity of Entergy and the Utility operating companies. In addition, multiple lawsuits currently are pending against emitters of greenhouse gases alleging that these companies are liable for personal injuries and property damage caused by climate change. These lawsuits seek injunctive relief, monetary compensation, and punitive damages.

In addition to the regulatory and financial risks associated with climate change discussed above, physical risks from climate change include an increase in sea level, wetland and barrier island erosion, risks of flooding and changes in weather conditions, such as changes in precipitation, average temperatures and potential increased impacts of extreme weather conditions or storms. Entergy subsidiaries own assets in, and serve, communities that are at risk from sea level rise, changes in weather conditions, storms and loss of the protection offered by coastal wetlands. A significant portion of the nation’s oil and gas infrastructure is located in these areas and susceptible to storm damage that could be aggravated by wetland and barrier island erosion, which could give rise to fuel supply interruptions and price spikes.

These and other physical changes could result in changes in customer demand, increased costs associated with repairing and maintaining generation facilities and transmission and distribution systems resulting in increased maintenance and capital costs (and potential increased financing needs), limits on the Entergy System's ability to meet peak customer demand, increased regulatory oversight, and lower customer satisfaction. Also, to the extent that climate change adversely impacts the economic health of a region or results in energy conservation or demand side management programs, it may adversely impact customer demand and revenues. Such physical or operational risks could have a material effect on Entergy's and the Utility operating companies' financial condition, results of operations and liquidity.

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Entergy and its subsidiaries may not be adequately hedged against changes in commodity prices, which could materially affect Entergy's and its subsidiaries' results of operations, financial condition and liquidity.

To manage their near-term financial exposure related to commodity price fluctuations, Entergy and its subsidiaries, including the Utility operating companies and the Entergy Wholesale Commodities business, may enter into contracts to hedge portions of their purchase and sale commitments, fuel requirements and inventories of natural gas, uranium (and its conversion), coal, refined products, and other commodities, within established risk management guidelines. As part of this strategy, Entergy and its subsidiaries may utilize fixed- and variable-price forward physical purchase and sales contracts, futures, financial swaps, and option contracts traded in the over-the-counter markets or on exchanges. However, Entergy and its subsidiaries normally cover only a portion of the exposure of their assets and positions to market price volatility, and the coverage will vary over time. In addition, Entergy also elects to leave certain volumes during certain years unhedged. To the extent Entergy and its subsidiaries have unhedged positions, fluctuating commodity prices can materially affect Entergy's and its subsidiaries' results of operations and financial position.

Although Entergy and its subsidiaries devote a considerable effort to these risk management strategies, they cannot eliminate all the risks associated with these activities. As a result of these and other factors, Entergy and its subsidiaries cannot predict with precision the impact that risk management decisions may have on their business, results of operations or financial position.

Entergy has guaranteed or indemnified the performance of a portion of the obligations relating to hedging and risk management activities. Reductions in Entergy's or its subsidiaries' credit quality or changes in the market prices of energy commodities could increase the cash or letter of credit collateral required to be posted in connection with hedging and risk management activities, which could materially affect Entergy's or its subsidiaries' liquidity and financial position.

The Utility operating companies and the Entergy Wholesale Commodities business are exposed to the risk that counterparties may not meet their obligations, which may materially affect the Utility operating companies and Entergy Wholesale Commodities.

The hedging and risk management practices of the Utility operating companies and the Entergy Wholesale Commodities business are exposed to the risk that counterparties that owe Entergy and its subsidiaries money, energy, or other commodities will not perform their obligations. Currently, some hedging agreements contain provisions that require the counterparties to provide credit support to secure their obligations to Entergy or its subsidiaries. If the counterparties to these arrangements fail to perform, Entergy or its subsidiaries may enforce and recover the proceeds from the credit support provided and acquire alternative hedging arrangements or draw on the credit support provided by the counterparties, which credit support may not always be adequate to cover the related obligations. In such event, Entergy and its subsidiaries might incur losses in addition to amounts, if any, already paid to the counterparties. In addition, the credit commitments of Entergy's lenders under its bank facilities may not be honored for a variety of reasons, including unexpected periods of financial distress affecting such lenders, which could materially affect the adequacy of its liquidity sources.

The Wall Street Transparency and Accountability Act of 2010 and rules and regulations promulgated under the act may adversely affect the ability of the Utility operating companies and the Entergy Wholesale Commodities business to utilize certain commodity derivatives for hedging and mitigating commercial risk.

The Wall Street Transparency and Accountability Act of 2010, which was enacted on July 21, 2010 as part of the Dodd-Frank Act Wall Street Reform and Consumer Protection Act, and the rules and regulations to be promulgated under the act will impose governmental regulation on the over-the-counter derivative market, including the commodity swaps used by the Utility operating companies and the Entergy Wholesale Commodities business to hedge and mitigate commercial risk. Under the act, certain swaps will be subject to mandatory clearing and exchange trading requirements. Swap dealers and major participants in the swap market will be subject to capital, margin, registration, reporting, recordkeeping and business conduct requirements with respect to their swap activities. Position limits will also apply to certain swaps activities. The act requires the applicable regulators, which in the case of commodity swaps will be the Commodity Futures Trading Commission, to engage in substantial rulemaking in order to implement the provisions of the act and such rulemaking is not yet final. Both the Utility operating companies

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and the Entergy Wholesale Commodities business currently utilize commodity swaps to hedge and mitigate commodity price risk. It is not known whether the act and regulations promulgated under the act will have an adverse effect upon the market for the commodity swaps used by the Utility operating companies and the Entergy Wholesale Commodities business. However, to the extent that the act and regulations promulgated under the act have the effect of increasing the price of such commodity swaps or limiting or reducing the availability of such commodity swaps, whether through the imposition of additional capital, margin or compliance costs upon market participants or otherwise, the financial performance of the Utility operating companies and/or the Entergy Wholesale Commodities business may be adversely affected. To the extent that the Utility operating companies and the Entergy Wholesale Commodities business would be required to post margin in connection with existing or future commodity swaps in addition to any margin currently posted by such entities, such entities may need to secure additional sources of capital to meet such liquidity needs or cease utilizing such commodity swaps.

Market performance and other changes may decrease the value of benefit plan assets, which then could require additional funding.

The performance of the capital markets affects the values of the assets held in trust under Entergy's pension and postretirement benefit plans. A decline in the market value of the assets may increase the funding requirements relating to Entergy's benefit plan liabilities. The recent recession and volatility in the capital markets have affected the market value of these assets, which may affect Entergy's planned levels of contributions in the future. Additionally, changes in interest rates affect the liabilities under Entergy's pension and postretirement benefit plans; as interest rates decrease, the liabilities increase, potentially requiring additional funding. The funding requirements of the obligations related to the pension benefit plans can also increase as a result of changes in, among other factors, retirement rates, life expectancy assumptions, or Federal regulations. Guidance pursuant to the Pension Protection Act of 2006 rules, effective for the 2008 plan year and beyond, continues to evolve, be interpreted through technical corrections bills and discussed within the industry and by congressional lawmakers. Any changes to the Pension Protection Act of 2006 as a result of these discussions and efforts may affect the level of Entergy's pension contributions in the future. For further information regarding Entergy's pension and other postretirement benefit plans, reference is made to the "Critical Accounting Estimates – Qualified Pension and Other Postretirement Benefits" section of Management's Financial Discussion and Analysis for Entergy and each of its Registrant Subsidiaries and Note 11 to the financial statements.

The litigation environment in the states in which certain Entergy subsidiaries operate poses a significant risk to those businesses.

Entergy and its subsidiaries are involved in the ordinary course of business in a number of lawsuits involving employment, commercial, asbestos, hazardous material and ratepayer matters, and injuries and damages issues, among other matters. The states in which the Utility operating companies operate, in particular Louisiana, Mississippi and Texas, have proven to be unusually litigious environments. Judges and juries in these states have demonstrated a willingness to grant large verdicts, including punitive damages, to plaintiffs in personal injury, property damage, and business tort cases. Entergy and its subsidiaries use legal and appropriate means to contest litigation threatened or filed against them, but the litigation environment in these states poses a significant business risk.

Terrorist attacks, including cyber attacks, and failures or breaches of Entergy’s and its subsidiaries’ technology systems may adversely affect Entergy’s results of operations.

As power generators and distributors, Entergy and its subsidiaries face heightened risk of an act or threat of terrorism, including physical and cyber attacks, either as a direct act against one of Entergy's generation facilities, an act against the transmission and distribution infrastructure used to transport power that affects its ability to operate, or an act against the information technology systems and network infrastructure of Entergy and its subsidiaries.

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Entergy and its subsidiaries operate in a highly regulated industry that requires the continued operation of sophisticated information technology systems and network infrastructure. Despite the implementation of security measures by Entergy and its subsidiaries, all technology systems are vulnerable to disability, failures, or unauthorized access due to such activities. If Entergy’s or its subsidiaries’ technology systems were to fail or be breached and be unable to recover in a timely way, Entergy or its subsidiaries may be unable to fulfill critical business functions, and sensitive confidential and other data could be compromised.

If any such attacks, failures or breaches were to occur, Entergy's and the Utility operating companies’ business, financial condition, and results of operations could be materially affected. The risk of such attacks, failures, or breaches also may cause Entergy and the Utility operating companies to incur increased capital and operating costs to implement increased security for its nuclear power plants and other facilities, such as additional physical facility security and additional security personnel, and for systems to protect its information technology and network infrastructure systems.

Changes in taxation as well as the inherent difficulty in quantifying potential tax effects of business decisions could negatively impact Entergy’s, the Utility operating companies’ and System Energy’s results of operations, financial condition and liquidity.

Entergy and its subsidiaries make judgments regarding the potential tax effects of various financial transactions and results of operations to estimate their obligations to taxing authorities. These tax obligations include income, franchise, real estate, sales and use and employment-related taxes. These judgments include reserves for potential adverse outcomes regarding tax positions that have been taken. Entergy and its subsidiaries also estimate their ability to utilize tax benefits, including those in the form of carryforwards for which the benefits have already been reflected in the financial statements. Changes in federal, state, or local tax laws, adverse tax audit results or adverse tax rulings on positions taken by Entergy and its subsidiaries could negatively affect Entergy's, the Utility operating companies' and System Energy's results of operations, financial condition and liquidity. For further information regarding Entergy's accounting for tax obligations, reference is made to Note 3 to the financial statements.

Entergy and the Utility operating companies may be unable to satisfy the conditions or obtain the approvals to complete the transaction with ITC or such approvals may contain material restrictions or conditions.

See “Plan to Spin Off the Utility’s Transmission Business” in Entergy Corporation’s Management’s Financial Discussion and Analysis for a discussion of the agreements that Entergy entered in December 2011 to spin off its transmission business and merge it with a newly-formed subsidiary of ITC Holdings Corp. The consummation of the ITC transaction is subject to numerous conditions, including (i) consummation of certain transactions and financings contemplated by the Merger Agreement and the Separation Agreement (such as the separation of the Transmission Business conducted by the Utility operating companies, (ii) obtaining the required ITC shareholder approvals, and (iii) the receipt of certain regulatory approvals from governmental agencies necessary to consummate the ITC transaction, and that no such regulatory approvals impose a burdensome condition on ITC or Entergy as described in the Merger Agreement. Entergy can make no assurances that the ITC transaction will be consummated on the terms or timeline currently contemplated, or at all. Governmental agencies may not approve the ITC transaction or may impose conditions to the approval of the ITC transaction or require changes to the terms of the ITC transaction. Any such conditions or changes could have the effect of delaying completion of the ITC transaction, imposing costs on or limiting the revenues of Entergy or the Utility operating companies or otherwise reducing the anticipated benefits of the ITC transaction. Any condition or change could result in a burdensome condition on the Transmission Business or ITC under the Merger Agreement and might cause Entergy or ITC to abandon the ITC transaction. In addition, Entergy must pay its costs related to the ITC transaction including, legal, accounting, advisory, financing and filing fees and printing costs, whether the ITC transaction is completed or not. Any failure to consummate the ITC transaction as currently contemplated, or at all, could have a material effect on the business and results of operations of Entergy and the Utility operating companies and the trading price of Entergy Corporation’s common stock could be adversely affected.

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(Entergy Gulf States Louisiana and Entergy New Orleans)

The effect of higher purchased gas cost charges to customers may adversely affect Entergy Gulf States Louisiana's and Entergy New Orleans' results of operations and liquidity.

Gas rates charged to retail gas customers are comprised primarily of purchased gas cost charges, which provide no return or profit to Entergy Gulf States Louisiana or Entergy New Orleans, and distribution charges, which provide a return or profit to the utility. Distribution charges are affected by the amount of gas sold to customers. Purchased gas cost charges, which comprise most of a customer's bill and may be adjusted quarterly, represent gas commodity costs that Entergy Gulf States Louisiana or Entergy New Orleans recovers from its customers. Entergy Gulf States Louisiana's or Entergy New Orleans' cash flows can be affected by differences between the time period when gas is purchased and the time when ultimate recovery from customers occurs. When purchased gas cost charges increase substantially reflecting higher gas procurement costs incurred by Entergy Gulf States Louisiana or Entergy New Orleans, customer usage may decrease, especially in weaker economic times, resulting in lower distribution charges for Entergy Gulf States Louisiana or Entergy New Orleans which could adversely affect results of operations.

(System Energy)

System Energy owns and operates a single nuclear generating facility, and it is dependent on affiliated companies for all of its revenues.

System Energy's operating revenues are derived from the allocation of the capacity, energy, and related costs associated with its 90% ownership/leasehold interest in Grand Gulf. Charges under the Unit Power Sales Agreement are paid by the Utility operating companies as consideration for their respective entitlements to receive capacity and energy. The useful economic life of Grand Gulf is finite and is limited by the terms of its operating license, which is currently due to expire on November 1, 2024. System Energy filed in October 2011 an application with the NRC for an extension of Grand Gulf’s operating license to 2045. The NRC accepted the filing in December 2011 and there is an expected NRC review period of 22 months before an order would be issued. System Energy's financial condition depends both on the receipt of payments from the Utility operating companies under the Unit Power Sales Agreement and on the continued commercial operation of Grand Gulf. For information regarding the Unit Power Sales Agreement and certain other agreements relating to the Entergy System companies' support of System Energy (including the Capital Funds Agreement), see the "Grand Gulf - Related Agreements" section of Note 8 to the financial statements and the "Utility - System Energy and Related Agreements" section of Part I, Item 1.

(Entergy Corporation)

Entergy Corporation's holding company structure could limit its ability to pay dividends.

Entergy Corporation is a holding company with no material assets other than the stock of its subsidiaries. Accordingly, all of its operations are conducted by its subsidiaries. Entergy Corporation's ability to pay dividends on its common stock depends on the payment to it of dividends or distributions by its subsidiaries. The payments of dividends or distributions to Entergy Corporation by its subsidiaries in turn depend on their results of operations and cash flows and other items affecting retained earnings, and on any applicable legal, regulatory, or contractual limitations on subsidiaries’ ability to pay such dividends or distributions. Provisions in the organizational documents, indentures for debt issuances, and other agreements of certain of Entergy Corporation's subsidiaries restrict the payment of cash dividends to Entergy Corporation. For further information regarding dividend or distribution restrictions to Entergy Corporation, reference is made to the "COMMON EQUITY – Retained Earnings and Dividend Restrictions" section of Note 7 to the financial statements.

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If completed, the transaction with ITC may not achieve its anticipated results.

Entergy entered into the ITC transaction with the expectation that it would result in various benefits, including the receipt by Entergy’s shareholders of shares of ITC common stock as a result of the transaction. If the ITC transaction is consummated, it is possible that the full strategic, financial, operational and regulatory benefits to Entergy and its shareholders that Entergy expected would result from the ITC transaction may not be achieved or that such benefits may be delayed or not occur due to unforeseen changes in market, economic or regulatory conditions or other events. As a result, the aggregate market price of the common stock of Entergy Corporation and the shares of ITC common stock that shareholders of Entergy Corporation would receive in the ITC transaction could be less than the market price of Entergy Corporation’s common stock if the ITC transaction had not occurred.

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ENTERGY ARKANSAS, INC. AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Plan to Spin Off the Utility’s Transmission Business

See the “Plan to Spin Off the Utility’s Transmission Business” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for a discussion of this matter, including the planned retirement of debt and preferred securities.

Results of Operations

Net Income

2011 Compared to 2010

Net income decreased $7.7 million primarily due to a higher effective income tax rate, lower other income, and higher other operation and maintenance expenses, substantially offset by higher net revenue, lower depreciation and amortization expenses, and lower interest expense.

2010 Compared to 2009

Net income increased $105.7 million primarily due to higher net revenue, a lower effective income tax rate, higher other income, and lower depreciation and amortization expenses, partially offset by higher other operation and maintenance expenses.

Net Revenue

2011 Compared to 2010

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges (credits). Following is an analysis of the change in net revenue comparing 2011 to 2010.

		Amount
		(In Millions)

2010 net revenue		$1,216.7
Retail electric price		31.0
ANO decommissioning trust		26.4
Transmission revenue		13.1
Volume/weather		(15.9)
Net wholesale revenue		(11.9)
Capacity acquisition recovery		(10.3)
Other		3.2
2011 net revenue		$1,252.3

The retail electric price variance is primarily due to a base rate increase effective July 2010. See Note 2 to the financial statements for more discussion of the rate case settlement.

The ANO decommissioning trust variance is primarily related to the deferral of investment gains from the ANO 1 and 2 decommissioning trust in 2010 in accordance with regulatory treatment. The gains resulted in an increase in 2010 in interest and investment income and a corresponding increase in regulatory charges with no effect on net income.

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Management’s Financial Discussion and Analysis

The transmission revenue variance is primarily due to a revision to transmission investment equalization billings under the Entergy System Agreement among the Utility operating companies (for the approximate period of 1996 – 2011) recorded in the fourth quarter 2011.

The volume/weather variance is primarily due to the effect of less favorable weather on residential and commercial sales, partially offset by more favorable weather-adjusted usage in the residential sector.

The net wholesale revenue variance is primarily due to lower margins on co-owner contracts and lower wholesale billings to affiliate companies due to lower expenses.

The capacity acquisition recovery variance is primarily due to the cessation of the capacity acquisition rider to recover expenses incurred because those costs are recovered in base rates effective July 2010.

Net Revenue

2010 Compared to 2009

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges. Following is an analysis of the change in net revenue comparing 2010 to 2009.

		Amount
		(In Millions)

2009 net revenue		$1,102.4
Volume/weather		84.2
Provision for regulatory proceedings		26.1
Retail electric price		16.1
2009 capitalization of Ouachita Plant service charges		12.5
ANO decommissioning trust		(24.4)
Net wholesale revenue		(12.2)
Other		12.0
2010 net revenue		$1,216.7

The volume/weather variance is primarily due to an increase of 2,078 GWh, or 10%, in billed electricity usage. Usage in the industrial sector increased primarily in the small industrial customers segment, as well as in the petroleum refining, chemicals, industrial inorganic, and pulp and paper industries, reflecting strong sales growth on continuing signs of economic recovery. The effect of more favorable weather was the primary driver of the increase in residential and commercial sales.

The provision for regulatory proceedings variance is primarily due to provisions recorded in 2009. See Note 2 to the financial statements for a discussion of regulatory proceedings affecting Entergy Arkansas.

The retail electric price variance is primarily due to a base rate increase effective July 2010, partially offset by the recovery in 2009 of 2008 extraordinary storm costs, as approved by the APSC, which ceased in January 2010. The recovery of storm costs is offset in other operation and maintenance expenses. See Note 2 to the financial statements for more discussion of the rate case settlement and the 2008 extraordinary storm costs.

In 2009, Entergy Arkansas capitalized $12.5 million of Ouachita Plant service charges that were previously expensed. The result of the capitalization in 2009 was a decrease in net revenues with an offsetting decrease in other operation and maintenance expenses.

The ANO decommissioning trust variance is primarily related to the deferral of investment gains from the ANO 1 and 2 decommissioning trust. The gains resulted in an increase in interest and investment income and a corresponding increase in regulatory charges with no effect on net income in accordance with regulatory treatment.

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Management’s Financial Discussion and Analysis

The net wholesale revenue variance is primarily due to reduced margin on wholesale contracts including lower capacity billings to an affiliate for the Ouachita unit that was later purchased by the affiliate in November 2009, and lower margins on co-owner contracts, somewhat offset by lower wholesale energy costs.

Gross operating revenues and fuel and purchased power expenses

Gross operating revenues decreased primarily due to:

·	a decrease of $98.6 million in rider revenues primarily due to lower System Agreement payments in 2010;

·	a decrease of $95.6 million in fuel cost recovery revenues due to a change in the energy cost recovery rider rate change effective April 2010; and

·	a decrease of $72.5 million in gross wholesale revenue due to decreased sales to affiliated customers and the expiration of a wholesale customer contract in 2009.

The decrease was offset by volume/weather, as discussed above.

Fuel and purchased power expenses decreased primarily due to a decrease in the average market price of purchased power.

Other Income Statement Variances

2011 Compared to 2010

Other operation and maintenance expenses increased primarily due to:

·	an increase of $6.1 million in fossil-fueled generation costs due to higher fossil plant outage costs due to a greater scope of work in 2011;

·	an increase of $3.9 million in transmission and distribution maintenance work in 2011;

·	$3.5 million in contract costs due to the transition and implementation of joining the MISO RTO; and

·	an increase of $3 million in nuclear expenses primarily due to higher labor and contract costs caused by several factors.

The increase was offset by a $7.5 million decrease in compensation and benefits costs primarily resulting from an increase in the accrual for incentive-based compensation in 2010 and a decrease in stock option expense.

Depreciation and amortization expenses decreased primarily due to a decrease in depreciation rates as a result of the rate case settlement agreement approved by the APSC in June 2010.

Other income decreased primarily due to the investment gains on the ANO 1 and 2 decommissioning trust in 2010, as discussed above in net revenue, and the carrying charges on storm restoration costs recorded in 2010 related to the January 2009 ice storm. See Note 2 to the financial statements for further discussion of the 2009 ice storm costs and Note 5 to the financial statements for a discussion of the August 2010 issuance of securitization bonds to finance these costs.

Interest expense decreased primarily due to the refinancing of debt at lower interest rates.

2010 Compared to 2009

Other operation and maintenance expenses increased primarily due to:

an increase of $21.7 million in compensation and benefits costs, resulting from decreasing discount rates, the amortization of benefit trust asset losses, and an increase in the accrual for incentive-based compensation. See Note 11 to the financial statements for further discussion of benefits costs;

·	an increase of $6.2 million in vegetation and maintenance expenses; and

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·	an increase of $5.4 million in nuclear expenses primarily due to higher labor costs, higher materials costs, and additional projects.

The increase was partially offset by a decrease of $19.4 million due to 2008 storm costs which were deferred per an APSC order and were recovered through revenues in 2009.

Depreciation and amortization expenses decreased primarily due to a decrease in depreciation rates as a result of the rate case settlement agreement approved by the APSC in June 2010.

Other income increased primarily due to the investment gains on the ANO 1 and 2 decommissioning trust discussed above in net revenue.

Income Taxes

The effective income tax rates for 2011, 2010, and 2009 were 44.6%, 39.6%, and 55.0%, respectively. See Note 3 to the financial statements for a reconciliation of the federal statutory rate of 35.0% to the effective income tax rates.

Liquidity and Capital Resources

In April 2011, several thunderstorms with either tornados or straight-line winds caused damage to Entergy Arkansas’s transmission and distribution lines, equipment poles, and other facilities. The incurred cost of repairing that damage is $70 million, of which $19 million is operating and maintenance costs that are charged against the storm cost provision, and the remainder is capital investment.

Cash Flow

Cash flows for the years ended December 31, 2011, 2010, and 2009 were as follows:

		2011	2010	2009
		(In Thousands)

Cash and cash equivalents at beginning of period		$106,102	$86,233	$39,568

Cash flow provided by (used in):
	Operating activities	564,124	512,260	384,192
	Investing activities	(503,524)	(413,180)	(281,512)
	Financing activities	(144,103)	(79,211)	(56,015)
	Net increase (decrease) in cash and cash equivalents	(83,503)	19,869	46,665

Cash and cash equivalents at end of period		$22,599	$106,102	$86,233

Operating Activities

Cash flow from operations increased $51.9 million in 2011 primarily due to:

income tax refunds of $90 million in 2011 compared to income tax payments of $66.4 million in 2010. In 2011, Entergy Arkansas received tax cash refunds in accordance with the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement. The refunds result from a decrease in 2010 taxable income from what was previously estimated because of the recognition of additional repair expenses for tax purposes associated with a tax accounting change filed in 2010 and from the reversal of temporary differences for which Entergy Arkansas previously made cash tax payments; and

·	a decrease of $16.6 million in pension contributions. See “Critical Accounting Estimates” below for a discussion of qualified pension and other postretirement benefits funding.

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The increase was offset by under-recovery of fuel costs and spending resulting from the April 2011 storms discussed above.

Cash flow from operations increased $128.1 million in 2010 compared to 2009 primarily due to an increase in net revenue as discussed above, ice storm spending in 2009, and the collection of previously under-recovered fuel costs through the normal operation of the energy cost recovery rider. The increase was offset by an increase of $112 million in pension contributions, and an increase of $65 million in income tax payments. See “Critical Accounting Estimates” below for a discussion of qualified pension and other postretirement benefits funding. In 2010 Entergy Arkansas made tax payments in accordance with the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement. The payments resulted from the reversal of temporary differences for which Entergy Arkansas previously received cash tax benefits and from estimated federal income tax payments for tax year 2010.

Investing Activities

Net cash flow used in investing activities increased $90.3 million in 2011 primarily due to an increase of $66.3 million in nuclear fuel purchases primarily due to the purchase of nuclear fuel inventory from System Fuels because the Utility companies will now purchase nuclear fuel throughout the nuclear fuel procurement cycle, rather than purchasing it from System Fuels at the time of refueling. The increase is also due to $51 million in storm restoration spending resulting from the April storms as discussed above, and $30 million in transmission substation reliability work in 2011. The increase was partially offset by money pool activity.

Decreases in Entergy Arkansas’s receivable from the money pool are a source of cash flow, and Entergy Arkansas’s receivable from the money pool decreased by $24.1 million in 2011 compared to increasing by $12.6 million in 2010. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Net cash flow used in investing activities increased $131.7 million in 2010 compared to 2009 primarily due to:

·	the sale to Entergy Gulf States Louisiana of one-third of the Ouachita plant for $75 million in 2009;

·	proceeds from the sale/leaseback of nuclear fuel of $118.6 million in 2009. See Note 18 to the financial statements for a discussion of the consolidation of the nuclear fuel company variable interest entity effective January 1, 2010; and

·	increases in nuclear construction expenditures primarily due to the ANO 1 reactor coolant pump upgrade project and security upgrades.

The increase was offset by a decrease in distribution construction expenditures as a result of an ice storm hitting Entergy Arkansas’s service territory in the first quarter 2009.

Financing Activities

Net cash flow used in financing activities increased $64.9 million in 2011 primarily due to:

the issuance of $575 million of first mortgage bonds by Entergy Arkansas and $124.1 million of storm cost recovery bonds by Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas, in 2010 compared to the issuance of the $55 million Series J note by the nuclear fuel company variable interest entity in 2011; and

·	a decrease in borrowings on the nuclear fuel company variable interest entity’s credit facility.

The increase was offset by:

·	the retirement of $450 million of first mortgage bonds and $139.5 million of pollution control revenue bonds in 2010 compared to the retirement of the $35 million Series G note by the nuclear fuel company variable interest entity in 2011; and

·	a decrease of $55.6 million in common stock dividends in 2011.

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Net cash flow used in financing activities increased $23.2 million in 2010 compared to 2009 primarily due to:

·	retirements of $450 million of first mortgage bonds in 2010;

·	retirements of $139.5 million of pollution control bonds in 2010; and

·	an increase of $125.1 million in common stock dividends paid in 2010.

The increase was offset by:

·	issuances of $575 million of first mortgage bonds in 2010; and

·	the issuance in August 2010 of $124.1 million of storm cost recovery bonds by Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas.

See Note 5 to the financial statements for details of long-term debt.

Capital Structure

Entergy Arkansas’s capitalization is balanced between equity and debt, as shown in the following table.

	December 31, 2011	December 31, 2010

Debt to capital	55.0%	55.9%
Effect of excluding the securitization bonds	(1.5)%	(1.6)%
Debt to capital, excluding securitization bonds (1)	53.5%	54.3%
Effect of subtracting cash	(0.3)%	(1.5)%
Net debt to net capital, excluding securitization bonds (1)	53.2%	52.8%

(1)	Calculation excludes the securitization bonds, which are non-recourse to Entergy Arkansas.

Net debt consists of debt less cash and cash equivalents. Debt consists of notes payable, capital lease obligations, and long-term debt, including the currently maturing portion. Capital consists of debt, preferred stock without sinking fund, and common equity. Net capital consists of capital less cash and cash equivalents. Entergy Arkansas uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Arkansas’s financial condition.

Uses of Capital

Entergy Arkansas requires capital resources for:

·	construction and other capital investments;

·	debt and preferred stock maturities or retirements;

·	working capital purposes, including the financing of fuel and purchased power costs; and

·	dividend and interest payments.

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Management’s Financial Discussion and Analysis

Following are the amounts of Entergy Arkansas’s planned construction and other capital investments, existing debt and lease obligations (includes estimated interest payments), and other purchase obligations:

	2012	2013-2014	2015-2016	after 2016	Total
	(In Millions)
Planned construction and capital investment (1):
Generation	$359	$207	N/A	N/A	$566
Transmission	117	242	N/A	N/A	359
Distribution	122	254	N/A	N/A	376
Other	26	37	N/A	N/A	63
Total	$624	$740	N/A	N/A	$1,364
Long-term debt (2)	$84	$538	$175	$2,070	$2,867
Capital lease payments	$0.2	$0.5	$0.2	$-	$0.9
Operating leases	$23	$42	$29	$5	$99
Purchase obligations (3)	$646	$1,201	$618	$1,792	$4,257

(1)	Includes approximately $234 million annually for maintenance capital, which is planned spending on routine capital projects that are necessary to support reliability of service, equipment or systems and to support normal customer growth.
(2)	Includes estimated interest payments. Long-term debt is discussed in Note 5 to the financial statements.
(3)	Purchase obligations represent the minimum purchase obligation or cancellation charge for contractual obligations to purchase goods or services. For Entergy Arkansas, almost all of the total consists of unconditional fuel and purchased power obligations, including its obligations under the Unit Power Sales Agreement, which is discussed in Note 8 to the financial statements.

In addition, Entergy Arkansas currently expects to contribute approximately $31.9 million to its pension plans and approximately $26.7 million to other postretirement plans in 2012 although the required pension contributions will not be known with more certainty until the January 1, 2012 valuations are completed by April 1, 2012.

Also in addition to the contractual obligations, Entergy Arkansas has $113.1 million of unrecognized tax benefits and interest net of unused tax attributes for which the timing of payments beyond 12 months cannot be reasonably estimated due to uncertainties in the timing of effective settlement of tax positions. See Note 3 to the financial statements for additional information regarding unrecognized tax benefits.

The planned capital investment estimate for Entergy Arkansas reflects capital required to support existing business and customer growth. Entergy’s Utility supply plan initiative will continue to seek to transform its generation portfolio with new or repowered generation resources. Opportunities resulting from the supply plan initiative, including new projects or the exploration of alternative financing sources, could result in increases or decreases in the capital expenditure estimates given above. The estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints, environmental compliance, market volatility, economic trends, business restructuring, changes in project plans, the ability to access capital, and the outcome of Entergy Arkansas’s exit from the Entergy System Agreement (which is discussed in “System Agreement” in the “Rate, Cost-recovery, and Other Regulation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis). Management provides more information on long-term debt and preferred stock maturities in Notes 5 and 6 to the financial statements.

As a wholly-owned subsidiary, Entergy Arkansas pays dividends to Entergy Corporation from its earnings at a percentage determined monthly. Entergy Arkansas’s long-term debt indentures restrict the amount of retained earnings available for the payment of cash dividends or other distributions on its common and preferred stock. As of December 31, 2011, Entergy Arkansas had restricted retained earnings unavailable for distribution to Entergy Corporation of $394.9 million.

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Hot Spring Energy Facility Purchase Agreement

In April 2011, Entergy Arkansas announced that it signed an asset purchase agreement to acquire the Hot Spring Energy Facility, a 620 MW natural gas-fired combined-cycle turbine plant located in Hot Spring County, Arkansas, from a subsidiary of KGen Power Corporation. The purchase price is expected to be approximately $253 million. Entergy Arkansas also expects to invest in various plant upgrades at the facility after closing and expects the total cost of the acquisition, including plant upgrades, transaction costs, and contingencies, to be approximately $277 million. A new transmission service request has been submitted to the ICT to determine if investments for supplemental upgrades in the Entergy transmission system are needed to make energy from the Hot Spring Energy Facility deliverable to Entergy Arkansas for the period after Entergy Arkansas exits the System Agreement. The initial results of the service request were received in January 2012 and indicate that available transfer capability does not exist with existing transmission facilities and that upgrades are required. The studies do not provide a final and definitive indication of what those upgrades would be. Entergy Arkansas has submitted transmission service requests for facilities studies which, when performed by the ICT, will provide more detailed estimates of the transmission upgrades and the associated costs required to obtain network service for the Hot Spring plant. Accordingly there are still uncertainties that must be resolved. The purchase is contingent upon, among other things, obtaining necessary approvals, including full cost recovery, from various federal and state regulatory and permitting agencies. These include regulatory approvals from the APSC and the FERC, as well as clearance under the Hart-Scott-Rodino anti-trust law. In February 2012 the FERC issued an order approving the acquisition. Closing is expected to occur in mid-2012.

Sources of Capital

Entergy Arkansas’s sources to meet its capital requirements include:

·	internally generated funds;

·	cash on hand;

·	debt or preferred stock issuances; and

·	bank financing under new or existing facilities.

Entergy Arkansas may refinance, redeem, or otherwise retire debt and preferred stock prior to maturity, to the extent market conditions and interest and dividend rates are favorable.

All debt and common and preferred stock issuances by Entergy Arkansas require prior regulatory approval. Preferred stock and debt issuances are also subject to issuance tests set forth in Entergy Arkansas’s corporate charters, bond indentures, and other agreements. Entergy Arkansas has sufficient capacity under these tests to meet its foreseeable capital needs.

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Management’s Financial Discussion and Analysis

Entergy Arkansas’s receivables from the money pool were as follows as of December 31 for each of the following years:

2011	2010	2009	2008
(In Thousands)

$17,362	$41,463	$28,859	$15,991

In April 2011, Entergy Arkansas entered into a new $78 million credit facility that expires in April 2012. There were no outstanding borrowings under the Entergy Arkansas credit facility as of December 31, 2011.

Entergy Arkansas has obtained short-term borrowing authorization from the FERC under which it may borrow through October 2013, up to the aggregate amount, at any one time outstanding, of $250 million. See Note 4 to the financial statements for further discussion of Entergy Arkansas’s short-term borrowing limits. Entergy Arkansas has also obtained an order from the APSC authorizing long-term securities issuances through December 2012.

State and Local Rate Regulation and Fuel-Cost Recovery

Retail Rates

2009 Base Rate Filing

Production Cost Allocation Rider

The APSC approved a production cost allocation rider for recovery from customers of the retail portion of the costs allocated to Entergy Arkansas as a result of the System Agreement proceedings. These costs cause an increase in Entergy Arkansas’s deferred fuel cost balance, because Entergy Arkansas pays the costs over seven months but collects them from customers over twelve months.

See Note 2 to the financial statements and Entergy Corporation and Subsidiaries “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - System Agreement” for discussions of the System Agreement proceedings.

Energy Cost Recovery Rider

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Management’s Financial Discussion and Analysis

Storm Cost Recovery

Entergy Arkansas January 2009 Ice Storm

Federal Regulation

See “Independent Coordinator of Transmission”, “System Agreement”, “Entergy’s Proposal to Join the MISO RTO”, “Notice to SERC Reliability Corporation Regarding Reliability Standards and FERC Investigation”, and “U.S. Department of Justice Investigation” in the “Rate, Cost-recovery, and Other Regulation – Federal Regulation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for a discussion of these topics.

Nuclear Matters

Entergy Arkansas owns and operates, through an affiliate, the ANO 1 and ANO 2 nuclear power plants. Entergy Arkansas is, therefore, subject to the risks related to owning and operating nuclear plants. These include risks from the use, storage, handling and disposal of high-level and low-level radioactive materials, regulatory requirement changes, including changes resulting from events at other plants, limitations on the amounts and types of insurance commercially available for losses in connection with nuclear operations, and technological and financial uncertainties related to decommissioning nuclear plants at the end of their licensed lives, including the sufficiency of funds in decommissioning trusts. In the event of an unanticipated early shutdown of either ANO 1 or ANO 2, Entergy Arkansas may be required to file with the APSC a rate mechanism to provide additional funds or credit support to satisfy regulatory requirements for decommissioning.

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Management’s Financial Discussion and Analysis

The nuclear industry continues to address susceptibility to stress corrosion cracking of certain materials associated with components within the reactor coolant system. The issue is applicable to ANO and is managed in accordance with industry standard practices and guidelines and includes in-service examinations, replacement and mitigation strategy. Several major modifications to the ANO units have been implemented to mitigate the susceptibility of large bore dissimilar metal welds. In addition, a replacement reactor vessel head has been fabricated for ANO 2 and is onsite. Routine inspections of the existing ANO 2 reactor vessel head have identified no significant material degradation issues for that component. These inspections will continue at planned refueling outages. Timing for installation of the new reactor vessel head will be based on the results of future inspection efforts.

Environmental Risks

Entergy Arkansas’s facilities and operations are subject to regulation by various governmental authorities having jurisdiction over air quality, water quality, control of toxic substances and hazardous and solid wastes, and other environmental matters. Management believes that Entergy Arkansas is in substantial compliance with environmental regulations currently applicable to its facilities and operations. Because environmental regulations are subject to change, future compliance costs cannot be precisely estimated.

Critical Accounting Estimates

The preparation of Entergy Arkansas’s financial statements in conformity with generally accepted accounting principles requires management to apply appropriate accounting policies and to make estimates and judgments that can have a significant effect on reported financial position, results of operations, and cash flows. Management has identified the following accounting policies and estimates as critical because they are based on assumptions and measurements that involve a high degree of uncertainty, and the potential for future changes in the assumptions and measurements that could produce estimates that would have a material effect on the presentation of Entergy Arkansas’s financial position or results of operations.

Nuclear Decommissioning Costs

See “Nuclear Decommissioning Costs” in the “Critical Accounting Estimates” section of Entergy Corporation and Subsidiaries Management’s Discussion and Analysis for discussion of the estimates inherent in accounting for nuclear decommissioning costs.

Unbilled Revenue

As discussed in Note 1 to the financial statements, Entergy Arkansas records an estimate of the revenues earned for energy delivered since the latest customer billing. Each month the estimated unbilled revenue amounts are recorded as revenue and a receivable, and the prior month’s estimate is reversed. The difference between the estimate of the unbilled receivable at the beginning of the period and the end of the period is the amount of unbilled revenue recognized during the period. The estimate recorded is primarily based upon an estimate of customer usage during the unbilled period and the billed price to customers in that month. Therefore, revenue recognized may be affected by the estimated price and usage at the beginning and end of each period, in addition to changes in certain components of the calculation.

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Management’s Financial Discussion and Analysis

Qualified Pension and Other Postretirement Benefits

Entergy sponsors qualified, defined benefit pension plans which cover substantially all employees. Additionally, Entergy currently provides postretirement health care and life insurance benefits for substantially all employees who reach retirement age and meet certain eligibility requirements while still working for Entergy. Entergy’s reported costs of providing these benefits, as described in Note 11 to the financial statements, are impacted by numerous factors including the provisions of the plans, changing employee demographics, and various actuarial calculations, assumptions, and accounting mechanisms. See the “Critical Accounting Estimates” section of Entergy Corporation and Subsidiaries Management’s Discussion and Analysis for further discussion. Because of the complexity of these calculations, the long-term nature of these obligations, and the importance of the assumptions utilized, Entergy’s estimate of these costs is a critical accounting estimate.

Cost Sensitivity

The following chart reflects the sensitivity of qualified pension cost and qualified projected benefit obligation to changes in certain actuarial assumptions (dollars in thousands):

Actuarial Assumption	Change in Assumption	Impact on 2011 Qualified Pension Cost	Impact on Qualified Projected Benefit Obligation
	Increase/(Decrease)

Discount rate	(0.25%)	$2,964	$37,338
Rate of return on plan assets	(0.25%)	$1,837	-
Rate of increase in compensation	0.25%	$1,218	$6,706

The following chart reflects the sensitivity of postretirement benefit cost and accumulated postretirement benefit obligation to changes in certain actuarial assumptions (dollars in thousands):

Actuarial Assumption	Change in Assumption	Impact on 2011 Postretirement Benefit Cost	Impact on Accumulated Postretirement Benefit Obligation
	Increase/(Decrease)

Health care cost trend	0.25%	$1,378	$8,340
Discount rate	(0.25%)	$972	$10,175

Each fluctuation above assumes that the other components of the calculation are held constant.

Costs and Funding

Total qualified pension cost for Entergy Arkansas in 2011 was $33.7 million. Entergy Arkansas anticipates 2012 qualified pension cost to be approximately $53 million. Entergy Arkansas’s contributions to the pension trust were $120.4 million in 2011 and are currently estimated to be approximately $31.9 million in 2012 although the required pension contributions will not be known with more certainty until the January 1, 2012 valuations are completed by April 1, 2012.

Total postretirement health care and life insurance benefit costs for Entergy Arkansas in 2011 were $17 million, including $6.3 million in savings due to the estimated effect of future Medicare Part D subsidies. Entergy Arkansas expects 2012 postretirement health care and life insurance benefit costs to approximate $18.1 million, including $5.8 million in savings due to the estimated effect of future Medicare Part D subsidies. Entergy Arkansas expects to contribute approximately $26.7 million to other postretirement plans in 2012.

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Federal Healthcare Legislation

See the “Qualified Pension and Other Postretirement Benefits - Federal Healthcare Legislation” in the “Critical Accounting Estimates” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for a discussion of Federal Healthcare Legislation.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Entergy Corporation and Subsidiaries Management’s Discussion and Analysis for further discussion.

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of

Entergy Arkansas, Inc. and Subsidiaries

Little Rock, Arkansas

We have audited the accompanying consolidated balance sheets of Entergy Arkansas, Inc. and Subsidiaries (the “Company”) as of December 31, 2011 and 2010, and the related consolidated income statements, consolidated statements of cash flows, and consolidated statements of changes in common equity (pages 274 through 278 and applicable items in pages 53 through 194) for each of the three years in the period ended December 31, 2011. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of Entergy Arkansas, Inc. and Subsidiaries as of December 31, 2011 and 2010, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2011, in conformity with accounting principles generally accepted in the United States of America.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control – Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 27, 2012 expressed an unqualified opinion on the Company’s internal control over financial reporting.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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CONSOLIDATED INCOME STATEMENTS

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands)

OPERATING REVENUES
Electric	$	2,084,310		$	2,082,447		$	2,211,263

OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale		186,036			378,699			298,219
Purchased power		659,464			485,447			795,526
Nuclear refueling outage expenses		42,557			41,800			42,148
Other operation and maintenance		511,592			495,443			475,222
Decommissioning		38,064			35,790			34,575
Taxes other than income taxes		82,847			85,564			80,829
Depreciation and amortization		218,902			232,085			252,742
Other regulatory charges (credits) - net		(13,506	)		1,603			15,161
TOTAL		1,725,956			1,756,431			1,994,422

OPERATING INCOME		358,354			326,016			216,841

OTHER INCOME
Allowance for equity funds used during construction		7,660			4,118			5,219
Interest and investment income		16,533			46,363			19,321
Miscellaneous - net		(4,172	)		(1,743	)		(3,569	)
TOTAL		20,021			48,738			20,971

INTEREST EXPENSE
Interest expense		83,545			91,598			92,340
Allowance for borrowed funds used during construction		(2,826	)		(2,406	)		(3,159	)
TOTAL		80,719			89,192			89,181

INCOME BEFORE INCOME TAXES		297,656			285,562			148,631

Income taxes		132,765			112,944			81,756

NET INCOME		164,891			172,618			66,875

Preferred dividend requirements and other		6,873			6,873			6,873

EARNINGS APPLICABLE TO
COMMON STOCK	$	158,018		$	165,745		$	60,002

See Notes to Financial Statements.

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CONSOLIDATED STATEMENTS OF CASH FLOWS

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands)

OPERATING ACTIVITIES
Net income	$	164,891		$	172,618		$	66,875
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		339,819			347,587			287,317
Deferred income taxes, investment tax credits, and non-current taxes accrued		94,410			100,071			66,777
Changes in assets and liabilities:
Receivables		(11,021	)		34,214			3,477
Fuel inventory		(11,190	)		(22,639	)		163
Accounts payable		160,983			(14,777	)		(338,993	)
Prepaid taxes and taxes accrued		122,974			(63,188	)		5,517
Interest accrued		2,861			426			(1,103	)
Deferred fuel costs		(148,274	)		61,300			(3,741	)
Other working capital accounts		(3,855	)		31,550			330,263
Provisions for estimated losses		(2,330	)		(5,247	)		(2,708	)
Other regulatory assets		(215,841	)		(87,087	)		(70,412	)
Pension and other postretirement liabilities		123,156			(32,496	)		6,501
Other assets and liabilities		(52,459	)		(10,072	)		34,259
Net cash flow provided by operating activities		564,124			512,260			384,192

INVESTING ACTIVITIES
Construction expenditures		(382,776	)		(291,267	)		(338,752	)
Allowance for equity funds used during construction		9,607			4,118			5,219
Nuclear fuel purchases		(148,657	)		(82,371	)		(118,379	)
Proceeds from sale of nuclear fuel		-			-			118,590
Proceeds from sale of equipment		-			2,489			74,818
Proceeds from nuclear decommissioning trust fund sales		125,408			367,266			154,644
Investment in nuclear decommissioning trust funds		(140,724	)		(400,832	)		(164,879	)
Change in money pool receivable - net		24,101			(12,604	)		(12,868	)
Changes in other investments - net		-			2,415			-
Investment in affiliates		10,994			-			-
Remittances to transition charge account		(15,650	)		(2,412	)		-
Payments from transition charge account		14,173			-			-
Other		-			18			95
Net cash flow used in investing activities		(503,524	)		(413,180	)		(281,512	)

FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		54,743			684,851			-
Retirement of long-term debt		(45,310	)		(589,500	)		-
Changes in credit borrowings - net		(28,863	)		5,711			-
Dividends paid:
Common stock		(117,800	)		(173,400	)		(48,300	)
Preferred stock		(6,873	)		(6,873	)		(6,873	)
Other		-			-			(842	)
Net cash flow used in financing activities		(144,103	)		(79,211	)		(56,015	)

Net increase (decrease) in cash and cash equivalents		(83,503	)		19,869			46,665

Cash and cash equivalents at beginning of period		106,102			86,233			39,568

Cash and cash equivalents at end of period	$	22,599		$	106,102		$	86,233

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid/(received) during the period for:
Interest - net of amount capitalized	$	75,650		$	85,639		$	88,397
Income taxes	$	(89,994	)	$	66,403		$	1,434

See Notes to Financial Statements.

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ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS

	December 31,
	2011			2010
	(In Thousands)

CURRENT ASSETS
Cash and cash equivalents:
Cash	$	4,712		$	4,250
Temporary cash investments		17,887			101,852
Total cash and cash investments		22,599			106,102
Securitization recovery trust account		3,890			2,412
Accounts receivable:
Customer		90,940			79,905
Allowance for doubtful accounts		(26,155	)		(24,402	)
Associated companies		58,030			82,583
Other		66,838			61,135
Accrued unbilled revenues		70,715			74,227
Total accounts receivable		260,368			273,448
Deferred fuel costs		209,776			61,502
Fuel inventory - at average cost		48,889			37,699
Materials and supplies - at average cost		143,343			140,095
Deferred nuclear refueling outage costs		49,047			23,099
System agreement cost equalization		36,800			52,160
Prepaid taxes		-			86,693
Prepayments and other		8,562			7,877
TOTAL		783,274			791,087

OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds		541,657			520,841
Non-utility property - at cost (less accumulated depreciation)		1,677			1,684
Other		3,182			14,176
TOTAL		546,516			536,701

UTILITY PLANT
Electric		8,079,732			7,787,348
Property under capital lease		1,234			1,303
Construction work in progress		120,211			114,324
Nuclear fuel		272,593			188,611
TOTAL UTILITY PLANT		8,473,770			8,091,586
Less - accumulated depreciation and amortization		3,833,596			3,683,001
UTILITY PLANT - NET		4,640,174			4,408,585

DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Regulatory asset for income taxes - net		87,357			98,836
Other regulatory assets (includes securitization property of
$105,762 as of December 31, 2011 and $118,505 as of
December 31, 2010)		1,126,911			892,449
Other		27,980			23,710
TOTAL		1,242,248			1,014,995

TOTAL ASSETS	$	7,212,212		$	6,751,368

See Notes to Financial Statements.

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ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY

	December 31,
	2011		2010
	(In Thousands)

CURRENT LIABILITIES
Currently maturing long-term debt	$	-	$	35,000
Short-term borrowings		33,914		62,777
Accounts payable:
Associated companies		228,163		92,627
Other		138,054		114,454
Customer deposits		81,074		72,535
Taxes accrued		36,281		-
Accumulated deferred income taxes		124,267		82,820
Interest accrued		29,881		27,020
Other		23,305		21,115
TOTAL		694,939		508,348

NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued		1,708,760		1,661,365
Accumulated deferred investment tax credits		42,939		44,928
Other regulatory liabilities		133,960		140,801
Decommissioning		640,228		602,164
Accumulated provisions		5,640		7,970
Pension and other postretirement liabilities		539,016		415,925
Long-term debt (includes securitization bonds of $113,761 as
of December 31, 2011 and $124,066 as of December 31, 2010)		1,875,921		1,828,910
Other		10,335		20,701
TOTAL		4,956,799		4,722,764

Commitments and Contingencies

Preferred stock without sinking fund		116,350		116,350

COMMON EQUITY
Common stock, $0.01 par value, authorized 325,000,000
shares; issued and outstanding 46,980,196 shares in 2011
and 2010		470		470
Paid-in capital		588,444		588,444
Retained earnings		855,210		814,992
TOTAL		1,444,124		1,403,906

TOTAL LIABILITIES AND EQUITY	$	7,212,212	$	6,751,368

See Notes to Financial Statements.

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ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN COMMON EQUITY
For the Years Ended December 31, 2011, 2010, and 2009

	Common Equity
	Common Stock		Paid-in Capital		Retained Earnings			Total
	(In Thousands)

Balance at December 31, 2008	$	470	$	588,444	$	810,945		$	1,399,859
Net income		-		-		66,875			66,875
Common stock dividends		-		-		(48,300	)		(48,300	)
Preferred stock dividends		-		-		(6,873	)		(6,873	)
Balance at December 31, 2009	$	470	$	588,444	$	822,647		$	1,411,561
Net income		-		-		172,618			172,618
Common stock dividends		-		-		(173,400	)		(173,400	)
Preferred stock dividends		-		-		(6,873	)		(6,873	)
Balance at December 31, 2010	$	470	$	588,444	$	814,992		$	1,403,906
Net income		-		-		164,891			164,891
Common stock dividends		-		-		(117,800	)		(117,800	)
Preferred stock dividends		-		-		(6,873	)		(6,873	)
Balance at December 31, 2011	$	470	$	588,444	$	855,210		$	1,444,124

See Notes to Financial Statements.

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ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON

	2011		2010		2009		2008		2007
	(In Thousands)

Operating revenues	$	2,084,310	$	2,082,447	$	2,211,263	$	2,328,349	$	2,032,965
Net Income	$	164,891	$	172,618	$	66,875	$	47,152	$	139,111
Total assets	$	7,212,212	$	6,751,368	$	6,492,802	$	6,568,213	$	5,999,806
Long-term obligations (1)	$	1,992,271	$	1,946,494	$	1,736,520	$	1,800,735	$	1,508,158

(1) Includes long-term debt (excluding currently maturing debt), noncurrent capital lease obligations, and preferred stock without sinking fund.

		2011		2010		2009		2008		2007
	(Dollars In Millions)
Electric Operating Revenues:
Residential	$	756	$	773	$	769	$	756	$	690
Commercial		450		441		475		463		409
Industrial		421		415		433		461		407
Governmental		20		20		21		21		19
Total retail		1,647		1,649		1,698		1,701		1,525
Sales for resale:
Associated companies		279		302		350		416		302
Non-associated companies		96		78		102		156		156
Other		62		53		61		55		50
Total	$	2,084	$	2,082	$	2,211	$	2,328	$	2,033
Billed Electric Energy Sales (GWh):
Residential		8,229		8,501		7,464		7,678		7,725
Commercial		6,051		6,144		5,817		5,875		5,945
Industrial		7,029		7,082		6,376		7,211		7,424
Governmental		275		277		269		274		277
Total retail		21,584		22,004		19,926		21,038		21,371
Sales for resale:
Associated companies		6,893		7,853		9,980		7,890		7,185
Non-associated companies		1,304		850		1,631		2,159		2,651
Total		29,781		30,707		31,537		31,087		31,207

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ENTERGY GULF STATES LOUISIANA, L.L.C.

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Plan to Spin Off the Utility’s Transmission Business

Results of Operations

Net Income

2011 Compared to 2010

Net income increased $12.3 million primarily due to lower interest expense and lower other operation and maintenance expenses, offset by higher depreciation and amortization expenses and a higher effective income tax rate.

2010 Compared to 2009

Net income increased $37.7 million primarily due to higher net revenue, a lower effective income tax rate, and lower interest expense, offset by higher other operation and maintenance expenses, lower other income, and higher taxes other than income taxes.

Net Revenue

2011 Compared to 2010

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory credits. Following is an analysis of the change in net revenue comparing 2011 to 2010.

		Amount
		(In Millions)

2010 net revenue		$933.6
Retail electric price		(20.1)
Volume/weather		(5.2)
Fuel recovery		14.8
Transmission revenue		12.4
Other		(2.1)
2011 net revenue		$933.4

The retail electric price variance is primarily due to an increase in credits passed on to customers as a result of the Act 55 storm cost financing. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Hurricane Gustav and Hurricane Ike” and Note 2 to the financial statements for a discussion of the Act 55 storm cost financing.

The volume/weather variance is primarily due to less favorable weather on the residential sector as well as the unbilled sales period. The decrease was partially offset by an increase of 62 GWh, or 0.3%, in billed electricity usage, primarily due to increased consumption by an industrial customer as a result of the customer’s cogeneration outage and the addition of a new production unit by the industrial customer.

The fuel recovery variance resulted primarily from an adjustment to deferred fuel costs in 2010. See Note 2 to the financial statements for a discussion of fuel recovery.

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Management’s Financial Discussion and Analysis

Fuel and purchased power expenses

Fuel and purchased power expenses increased primarily due to:

·	an increase in deferred fuel expense due to the timing of receipt of System Agreement payments and credits to customers;

·	an increase in natural gas fuel expense primarily due to increased generation; and

·	an increase in deferred fuel expense due to fuel and purchased power expense decreases in excess of lower fuel cost recovery revenues.

The increase was offset by a decrease in the average market price of purchased power and decreased net area demand.

2010 Compared to 2009

		Amount
		(In Millions)

2009 net revenue		$861.3
Retail electric price		66.7
Volume/weather		32.7
Fuel recovery		(28.7)
Other		1.6
2010 net revenue		$933.6

The retail electric price variance is primarily due to formula rate plan increases effective November 2009, January 2010, and September 2010. See Note 2 to the financial statements for further discussion of the formula rate plan increases.

The volume/weather variance is primarily due to an increase of 1,861 GWh, or 10%, in billed electricity usage, primarily in the industrial sector as a result of increased consumption in the chemicals industry, and also the effect of more favorable weather on the residential and commercial sectors.

Gross operating revenues and fuel and purchased power expenses

Gross operating revenues increased primarily due to:

·	an increase of $100.9 million in rider revenues due to lower System Agreement credits in 2010;

·	formula rate plan increases effective November 2009, January 2010, and September 2010, as noted above;

·	an increase of $64.5 million in fuel cost recovery revenues due to increased usage primarily in the industrial sector; and

·	the increase related to volume/weather, as discussed above.

The increase was partially offset by a decrease in gross wholesale revenues primarily due to the transfer of several wholesale customers to Entergy Texas in 2009 and decreased system agreement remedy receipts.

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Management’s Financial Discussion and Analysis

Fuel and purchased power expenses increased primarily due to an increase in the average market price of purchased power.

Other Income Statement Variances

2011 Compared to 2010

Nuclear refueling outage expenses decreased primarily due to the amortization of lower expenses associated with the planned maintenance and refueling outage at River Bend in the first quarter 2011.

Other operation and maintenance expenses decreased primarily due to:

·	a decrease of $6 million in fossil-fueled generation expenses primarily due to fewer outages and a reduced scope of work compared to 2010; and

·	a decrease of $4.2 million in compensation and benefits costs primarily resulting from an increase in the accrual for incentive-based compensation in 2010 and a decrease in stock option expense.

The decrease was partially offset by an increase of $2.9 million in costs due to the transition and implementation of joining the MISO RTO, as well as several individually insignificant items.

Depreciation and amortization expenses increased primarily due to a revision in the second quarter 2010 related to depreciation on storm cost-related assets and an increase in plant in service. Recovery of the storm cost-related assets will now be through the Act 55 financing of storm costs as approved by the LPSC in June 2010. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Hurricane Gustav and Hurricane Ike” and Note 2 to the financial statements for a discussion of the Act 55 storm cost financing.

Interest expense decreased primarily due to:

·	redemptions of first mortgage bonds of $68 million in June 2010 and $304 million in November 2010, partially offset by the issuance of first mortgage bonds of $250 million in October 2010. See Note 5 to the financial statements for a discussion of long-term debt; and

·	interest expense accrued in 2010 related to the expected result of the LPSC Staff audit of the fuel adjustment clause for the period 1995 through 2004. See Note 2 to the financial statements for a discussion of fuel recovery.

2010 Compared to 2009

Other operation and maintenance expenses increased primarily due to an increase of $12.4 million in fossil expenses due to higher plant maintenance costs and plant outages and a $12.1 million increase in compensation and benefits costs resulting from decreasing discount rates, the amortization of benefit trust asset losses, and an increase in the accrual for incentive-based compensation. See Note 11 to the financial statements for further discussion of benefit costs.

Taxes other than income taxes increased primarily due to an increase in local franchise taxes as a result of higher revenues primarily in the residential and commercial sectors and an increase in ad valorem taxes as a result of higher millage rates, a higher 2010 assessment, and a reduction in capitalized property taxes as compared to 2009.

Other income decreased primarily due to a decrease of $30.1 million in interest and investment income related to the debt assumption agreement with Entergy Texas. In June 2010, Entergy Texas repaid the outstanding assumed debt and the debt assumption agreement was terminated.

Interest expense decreased primarily due to a decrease in long-term debt outstanding as a result of redemptions of first mortgage bonds of $292 million in December 2009, $68 million in June 2010, and $304 million in November 2010, partially offset by issuances of first mortgage bonds of $300 million in October 2009 and $250 million in October 2010. See Note 5 to the financial statements for further discussion of the decrease in long-term debt.

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Management’s Financial Discussion and Analysis

Income Taxes

The effective income tax rates were 30.3%, 28.5%, and 36.8% for 2011, 2010, and 2009, respectively. See Note 3 to the financial statements for a reconciliation of the federal statutory rate of 35% to the effective income tax rates.

Liquidity and Capital Resources

Cash Flow

Cash flows for the years ended December 31, 2011, 2010, and 2009 were as follows:

		2011	2010	2009
		(In Thousands)

Cash and cash equivalents at beginning of period		$155,173	$144,460	$49,303

Cash flow provided by (used in):
	Operating activities	482,115	726,130	234,930
	Investing activities	(267,262)	(541,583)	(286,486)
	Financing activities	(345,181)	(173,834)	146,713
	Net increase (decrease) in cash and cash equivalents	(130,328)	10,713	95,157

Cash and cash equivalents at end of period		$24,845	$155,173	$144,460

Operating Activities

Net cash flow provided by operating activities decreased $244 million in 2011 compared to 2010 primarily due to:

·	proceeds of $240.3 million received from the LURC as a result of the Act 55 storm cost financings in 2010. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Hurricane Gustav and Hurricane Ike and Note 2 to the financial statements for a discussion of the Act 55 storm cost financing; and

·	higher nuclear refueling outage spending at River Bend. River Bend had a refueling outage in 2011 and did not have one in 2010.

The decrease was partially offset by income tax refunds of $56.3 million in 2011 compared to income tax refunds of $16.8 million in 2010. In 2011, Entergy Gulf States Louisiana received tax cash refunds in accordance with the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement. The refunds resulted from the reversal of temporary differences for which Entergy Gulf States Louisiana previously made cash tax payments.

Net cash flow provided by operating activities increased $491.2 million in 2010 compared to 2009 primarily due to:

·	storm cost proceeds of $240.3 million received from the LURC as a result of the Act 55 storm cost financings;

·	the absence in 2010 of the storm restoration spending that occurred in 2009. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Hurricane Gustav and Hurricane Ike and Note 2 to the financial statements for a discussion of the Act 55 storm cost financing; and

income tax refunds of $16.8 million in 2010 compared to income tax payments of $60.6 million in 2009. In 2010, Entergy Gulf States Louisiana received tax cash refunds in accordance with the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement. The refunds resulted from the reversal of temporary differences for which Entergy Gulf States Louisiana previously made cash tax payments.

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Management’s Financial Discussion and Analysis

Investing Activities

Net cash flow used in investing activities decreased $274.3 million in 2011 compared to 2010 primarily due to:

the investment in 2010 of $150.3 million in affiliate securities and the investment of $90.1 million in the storm reserve escrow account as a result of the Act 55 storm cost financings. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Hurricane Gustav and Hurricane Ike and Note 2 to the financial statements for a discussion of the Act 55 storm cost financing; and

·	money pool activity.

The decrease was partially offset by an increase in nuclear fuel purchases because River Bend had a refueling outage in 2011 and did not have one in 2010.

Decreases in Entergy Gulf States Louisiana’s receivable from the money pool are a source of cash flow, and Entergy Gulf States Louisiana’s receivable from the money pool decreased by $39.4 million in 2011 compared to increasing by $12.9 million in 2010. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Net cash flow used in investing activities increased $255.1 million in 2010 compared to 2009 primarily due to:

the investment of $150.3 million in affiliate securities and the investment of $90.1 million in the storm reserve escrow account as a result of the Act 55 storm cost financings. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Hurricane Gustav and Hurricane Ike and Note 2 to the financial statements for a discussion of the Act 55 storm cost financing;

·	proceeds from the sale/leaseback of nuclear fuel of $72.8 million in 2009. See Note 18 to the financial statements for discussion of the consolidation of nuclear fuel company variable interest entities effective January 1, 2010; and

·	an increase in construction expenditures primarily due to $24.9 million in costs associated with the development of new nuclear generation at River Bend. See “New Nuclear Development” below.

The increase was partially offset by the purchase of one-third (Unit 3) of the three-unit, 789 MW Ouachita Power Plant for $75 million in November 2009 from Entergy Arkansas and money pool activity.

Increases in Entergy Gulf States Louisiana’s receivable from the money pool are a use of cash flow, and Entergy Gulf States Louisiana’s receivable from the money pool increased by $12.9 million for the year ended December 31, 2010 compared to increasing by $38.5 million for the year ended December 31, 2009.

Financing Activities

Net cash flow used in financing activities increased $171.3 million in 2011 compared to 2010 primarily due to an increase of $177.7 million in common equity distributions.

Financing activities used cash of $173.8 million in 2010 compared to providing cash of $146.7 million in 2009 primarily due to:

·	net cash issuances of $178.2 million of long-term debt in 2009;

·	net cash redemptions of $38.6 million of long-term debt in 2010; and

·	an increase of $93.6 million in common equity distributions.

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Entergy Gulf States Louisiana, L.L.C.

Management’s Financial Discussion and Analysis

Capital Structure

Entergy Gulf States Louisiana’s capitalization is balanced between equity and debt, as shown in the following table. The increase in the debt to capital ratio for Entergy Gulf States Louisiana as of December 31, 2011 is primarily due to a decrease in member’s equity as a result of an increase of $177.6 million in common equity distributions.

	December 31, 2011	December 31, 2010

Debt to capital	52.2%	51.2%
Effect of subtracting cash	(0.4)%	(2.6)%
Net debt to net capital	51.8%	48.6%

Net debt consists of debt less cash and cash equivalents. Debt consists of notes payable and long-term debt, including the currently maturing portion. Capital consists of debt and members’ equity. Net capital consists of capital less cash and cash equivalents. Entergy Gulf States Louisiana uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Gulf States Louisiana’s financial condition.

Uses of Capital

Entergy Gulf States Louisiana requires capital resources for:

·	construction and other capital investments;

·	debt and preferred equity maturities or retirements;

·	working capital purposes, including the financing of fuel and purchased power costs; and

·	distribution and interest payments.

Following are the amounts of Entergy Gulf States Louisiana’s planned construction and other capital investments, existing debt and lease obligations (includes estimated interest payments), and other purchase obligations:

	2012	2013-2014	2015-2016	after 2016	Total
	(In Millions)
Planned construction and capital investment (1):
Generation	$67	$102	N/A	N/A	$169
Transmission	95	139	N/A	N/A	234
Distribution	59	132	N/A	N/A	191
Other	18	34	N/A	N/A	52
Total	$239	$407	N/A	N/A	$646
Long-term debt (2)	$141	$262	$203	$1,924	$2,530
Operating leases	$11	$29	$16	$66	$122
Purchase obligations (3)	$154	$237	$209	$54	$654

(1)	Includes approximately $152 million annually for maintenance capital, which is planned spending on routine capital projects that are necessary to support reliability of service, equipment or systems and to support normal customer growth.
(2)	Includes estimated interest payments. Long-term debt is discussed in Note 5 to the financial statements.
(3)	Purchase obligations represent the minimum purchase obligation or cancellation charge for contractual obligations to purchase goods or services. For Entergy Gulf States Louisiana, it primarily includes unconditional fuel and purchased power obligations.

In addition to the contractual obligations given above, Entergy Gulf States Louisiana expects to contribute $10.8 million to its pension plans and $8.3 million to other postretirement plans in 2012 although the required pension contributions will not be known with more certainty until the January 1, 2012 valuations are completed by April 1, 2012.

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Management’s Financial Discussion and Analysis

Also, in addition to the contractual obligations, Entergy Gulf States Louisiana has $318.6 million of unrecognized tax benefits and interest net of unused tax attributes for which the timing of payments beyond 12 months cannot be reasonably estimated due to uncertainties in the timing of effective settlement of tax positions. See Note 3 to the financial statements for additional information regarding unrecognized tax benefits.

The planned capital investment estimate for Entergy Gulf States Louisiana reflects capital required to support existing business and customer growth. Entergy’s Utility supply plan initiative will continue to seek to transform its generation portfolio with new or repowered generation resources. Opportunities resulting from the supply plan initiative, including new projects or the exploration of alternative financing sources, could result in increases or decreases in the capital expenditure estimates given above. The estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints, environmental compliance, market volatility, economic trends, business restructuring, changes in project plans, and the ability to access capital.

Management provides more information on long-term debt maturities in Note 5 to the financial statements.

As an indirect, wholly-owned subsidiary of Entergy Corporation, Entergy Gulf States Louisiana pays distributions from its earnings at a percentage determined monthly. Entergy Gulf States Louisiana’s long-term debt indentures contain restrictions on the payment of cash dividends or other distributions on its common and preferred membership interests.

New Nuclear Development

Entergy Gulf States Louisiana and Entergy Louisiana provided public notice to the LPSC of their intention to make a filing pursuant to the LPSC’s general order that governs the development of new nuclear generation in Louisiana. The project option being developed by the companies is for new nuclear generation at River Bend. Entergy Gulf States Louisiana and Entergy Louisiana, together with Entergy Mississippi, have been engaged in the development of options to construct new nuclear generation at the River Bend and Grand Gulf sites. Entergy Gulf States Louisiana and Entergy Louisiana are leading the development at River Bend, and Entergy Mississippi is leading the development at Grand Gulf. This project is in the early stages, and several issues remain to be addressed over time before significant additional capital would be committed to this project. In the first quarter 2010, Entergy Gulf States Louisiana and Entergy Louisiana each paid for and recognized on its books $24.9 million in costs associated with the development of new nuclear generation at the River Bend site; these costs previously had been recorded on the books of Entergy New Nuclear Utility Development, LLC, a System Energy subsidiary. Entergy Gulf States Louisiana and Entergy Louisiana will share costs going forward on a 50/50 basis, which reflects each company’s current participation level in the project. In March 2010, Entergy Gulf States Louisiana and Entergy Louisiana filed with the LPSC seeking approval to continue the development activities. The testimony and legal briefs of the LPSC staff generally support the request of Entergy Gulf States Louisiana and Entergy Louisiana, although other parties filed briefs, without supporting testimony, in opposition to the request. An evidentiary hearing was held in October 2011 and the ALJ’s decision is pending.

Sources of Capital

Entergy Gulf States Louisiana’s sources to meet its capital requirements include:

·	internally generated funds;

·	cash on hand;

·	debt or preferred membership interest issuances; and

·	bank financing under new or existing facilities.

Entergy Gulf States Louisiana may refinance, redeem, or otherwise retire debt and preferred equity/membership interests prior to maturity, to the extent market conditions and interest and dividend rates are favorable.

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Management’s Financial Discussion and Analysis

All debt and common and preferred equity/membership interest issuances by Entergy Gulf States Louisiana require prior regulatory approval. Preferred equity/membership interest and debt issuances are also subject to issuance tests set forth in its bond indentures and other agreements. Entergy Gulf States Louisiana has sufficient capacity under these tests to meet its foreseeable capital needs.

Entergy Gulf States Louisiana’s receivables from the money pool were as follows as of December 31 for each of the following years:

2011	2010	2009	2008
(In Thousands)

$23,596	$63,003	$50,131	$11,589

See Note 4 to the financial statements for a description of the money pool.

Entergy Gulf States Louisiana has a credit facility in the amount of $100 million scheduled to expire in August 2012. No borrowings were outstanding under the credit facility as of December 31, 2011.

Entergy Gulf States Louisiana obtained short-term borrowing authorization from the FERC under which it may borrow through October 2013, up to the aggregate amount, at any one time outstanding, of $200 million. See Note 4 to the financial statements for further discussion of Entergy Gulf States Louisiana’s short-term borrowing limits. Entergy Gulf States Louisiana has also obtained an order from the FERC authorizing long-term securities issuances through July 2013.

Hurricane Gustav and Hurricane Ike

In September 2008, Hurricane Gustav and Hurricane Ike caused catastrophic damage to Entergy Gulf States Louisiana’s service territory. The storms resulted in widespread power outages, significant damage to distribution, transmission, and generation infrastructure, and the loss of sales during the power outages. In October 2008, Entergy Gulf States Louisiana drew all of its $85 million funded storm reserve. On October 15, 2008, the LPSC approved Entergy Gulf States Louisiana’s request to defer and accrue carrying cost on unrecovered storm expenditures during the period the company seeks regulatory recovery. The approval was without prejudice to the ultimate resolution of the total amount of prudently incurred storm cost or final carrying cost rate.

Entergy Gulf States Louisiana and Entergy Louisiana filed their Hurricane Gustav and Hurricane Ike storm cost recovery case with the LPSC in May 2009. In September 2009, Entergy Gulf States Louisiana and Entergy Louisiana and the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, filed with the LPSC an application requesting that the LPSC grant financing orders authorizing the financing of Entergy Gulf States Louisiana’s and Entergy Louisiana’s storm costs, storm reserves, and issuance costs pursuant to Act 55 of the Louisiana Regular Session of 2007 (Act 55 financings). Entergy Gulf States Louisiana’s and Entergy Louisiana’s Hurricane Katrina and Hurricane Rita storm costs were financed primarily by Act 55 financings, as discussed below. Entergy Gulf States Louisiana and Entergy Louisiana also filed an application requesting LPSC approval for ancillary issues including the mechanism to flow charges and Act 55 financing savings to customers via a Storm Cost Offset rider.

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Management’s Financial Discussion and Analysis

In July 2010 the Louisiana Local Government Environmental Facilities and Community Development Authority (LCDA) issued $244.1 million in bonds under Act 55. From the $240.3 million of bond proceeds loaned by the LCDA to the LURC, the LURC deposited $90 million in a restricted escrow account as a storm damage reserve for Entergy Gulf States Louisiana and transferred $150.3 million directly to Entergy Gulf States Louisiana. From the bond proceeds received by Entergy Gulf States Louisiana from the LURC, Entergy Gulf States Louisiana used $150.3 million to acquire 1,502,643.04 Class B preferred, non-voting, membership interest units of Entergy Holdings Company LLC, a company wholly-owned and consolidated by Entergy, that carry a 9% annual distribution rate. Distributions are payable quarterly commencing on September 15, 2010, and the membership interests have a liquidation price of $100 per unit. The preferred membership interests are callable at the option of Entergy Holdings Company LLC after ten years under the terms of the LLC agreement. The terms of the membership interests include certain financial covenants to which Entergy Holdings Company LLC is subject, including the requirement to maintain a net worth of at least $1 billion.

Entergy Gulf States Louisiana does not report the bonds on its balance sheet because the bonds are the obligation of the LCDA, and there is no recourse against Entergy Gulf States Louisiana in the event of a bond default. To service the bonds, Entergy Gulf States Louisiana collects a system restoration charge on behalf of the LURC, and remits the collections to the bond indenture trustee. Entergy Gulf States Louisiana does not report the collections as revenue because it is merely acting as the billing and collection agent for the state.

Entergy Louisiana’s Ninemile Point Unit 6 Self-Build Project

State and Local Rate Regulation and Fuel-Cost Recovery

The rates that Entergy Gulf States Louisiana charges for its services significantly influence its financial position, results of operations, and liquidity. Entergy Gulf States Louisiana is regulated and the rates charged to its customers are determined in regulatory proceedings. A governmental agency, the LPSC is primarily responsible for approval of the rates charged to customers.

Retail Rates – Electric

In March 2005, the LPSC approved a settlement proposal to resolve various dockets covering a range of issues for Entergy Gulf States Louisiana and Entergy Louisiana. The settlement included the establishment of a three-year formula rate plan for Entergy Gulf States Louisiana that, among other provisions, establishes a return on common equity mid-point of 10.65% for the initial three-year term of the plan and permits Entergy Gulf States Louisiana to recover incremental capacity costs outside of a traditional base rate proceeding. Under the formula rate plan, over- and under-earnings outside an allowed range of 9.9% to 11.4% are allocated 60% to customers and 40% to Entergy Gulf States Louisiana. Entergy Gulf States Louisiana made its initial formula rate plan filing in June 2005. The formula rate plan was subsequently extended one year. As discussed below the formula rate plan has been extended, with return on common equity provisions consistent with previously approved provisions, to cover the 2008, 2009, 2010, and 2011 test years.

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Entergy Gulf States Louisiana, L.L.C.

Management’s Financial Discussion and Analysis

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Entergy Gulf States Louisiana, L.L.C.

Management’s Financial Discussion and Analysis

Retail Rates – Gas

In January 2009, Entergy Gulf States Louisiana filed with the LPSC its gas rate stabilization plan for the test year ending September 30, 2008. The filing showed a revenue deficiency of $529 thousand based on a return on common equity mid-point of 10.5%. In April 2009, Entergy Gulf States Louisiana implemented a $255 thousand rate increase pursuant to an uncontested settlement with the LPSC staff.

In January 2011, Entergy Gulf States Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2010. The filing showed an earned return on common equity of 8.84% and a revenue deficiency of $0.3 million. In March 2011, the LPSC Staff filed its findings, suggesting an adjustment that will produce an 11.76% earned return on common equity for the test year and a $0.2 million rate reduction. Entergy Gulf States Louisiana implemented the $0.2 million rate reduction effective with the May 2011 billing cycle. The LPSC docket is now closed.

Fuel and purchased power cost recovery

In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Gulf States Louisiana’s purchased gas adjustment clause filings for its gas distribution operations. The audit includes a review of the reasonableness of charges flowed through by Entergy Gulf States Louisiana for the period from 2003 through 2008. Discovery was completed and, in June 2011, the LPSC Staff filed an audit report generally supporting the appropriateness of charges flowed through the purchased gas adjustment clause filings. The LPSC approved the staff audit report in October 2011.

Industrial and Commercial Customers

Entergy Gulf States Louisiana’s large industrial and commercial customers continually explore ways to reduce their energy costs. In particular, cogeneration is an option available to a portion of Entergy Gulf States Louisiana’s industrial customer base. Entergy Gulf States Louisiana responds by working with industrial and commercial customers and negotiating electric service contracts to provide competitive rates that match specific customer needs and load profiles. Entergy Gulf States Louisiana actively participates in economic development, customer retention, and reclamation activities to increase industrial and commercial demand, from both new and existing customers. Entergy Gulf States Louisiana does not currently expect additional significant losses to cogeneration because of the current economics of the electricity markets and Entergy Gulf States Louisiana’s marketing efforts in retaining industrial customers.

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Entergy Gulf States Louisiana, L.L.C.

Management’s Financial Discussion and Analysis

Federal Regulation

Nuclear Matters

Entergy Gulf States Louisiana owns and, through an affiliate, operates the River Bend nuclear power plant. Entergy Gulf States Louisiana is, therefore, subject to the risks related to owning and operating a nuclear plant. These include risks from the use, storage, handling and disposal of high-level and low-level radioactive materials, regulatory requirement changes, including changes resulting from events at other plants, limitations on the amounts and types of insurance commercially available for losses in connection with nuclear operations, and technological and financial uncertainties related to decommissioning nuclear plants at the end of their licensed lives, including the sufficiency of funds in decommissioning trusts. In the event of an unanticipated early shutdown of River Bend, Entergy Gulf States Louisiana may be required to provide additional funds or credit support to satisfy regulatory requirements for decommissioning.

Environmental Risks

Entergy Gulf States Louisiana’s facilities and operations are subject to regulation by various governmental authorities having jurisdiction over air quality, water quality, control of toxic substances and hazardous and solid wastes, and other environmental matters. Management believes that Entergy Gulf States Louisiana is in substantial compliance with environmental regulations currently applicable to its facilities and operations. Because environmental regulations are subject to change, future compliance costs cannot be precisely estimated.

Critical Accounting Estimates

The preparation of Entergy Gulf States Louisiana’s financial statements in conformity with generally accepted accounting principles requires management to apply appropriate accounting policies and to make estimates and judgments that can have a significant effect on reported financial position, results of operations, and cash flows. Management has identified the following accounting policies and estimates as critical because they are based on assumptions and measurements that involve a high degree of uncertainty, and the potential for future changes in the assumptions and measurements that could produce estimates that would have a material effect on the presentation of Entergy’s financial position or results of operations.

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Entergy Gulf States Louisiana, L.L.C.

Management’s Financial Discussion and Analysis

Nuclear Decommissioning Costs

See “Nuclear Decommissioning Costs” in the “Critical Accounting Estimates” section of Entergy Corporation and Subsidiaries’ Management’s Discussion and Analysis for discussion of the estimates inherent in accounting for nuclear decommissioning costs.

Unbilled Revenue

As discussed in Note 1 to the financial statements, Entergy Gulf States Louisiana records an estimate of the revenues earned for energy delivered since the latest customer billing. Each month the estimated unbilled revenue amounts are recorded as revenue and a receivable, and the prior month’s estimate is reversed. The difference between the estimate of the unbilled receivable at the beginning of the period and the end of the period is the amount of unbilled revenue recognized during the period. The estimate recorded is primarily based upon an estimate of customer usage during the unbilled period and the billed price to customers in that month. Therefore, revenue recognized may be affected by the estimated price and usage at the beginning and end of each period, in addition to changes in certain components of the calculation.

Qualified Pension and Other Postretirement Benefits

Entergy sponsors qualified defined benefit pension plans which cover substantially all employees. Additionally, Entergy currently provides postretirement health care and life insurance benefits for substantially all employees who reach retirement age and meet certain eligibility requirements while still working for Entergy. Entergy’s reported costs of providing these benefits, as described in Note 11 to the financial statements, are impacted by numerous factors including the provisions of the plans, changing employee demographics, and various actuarial calculations, assumptions, and accounting mechanisms. See the “Critical Accounting Estimates” section of Entergy Corporation and Subsidiaries Management’s Discussion and Analysis for further discussion. Because of the complexity of these calculations, the long-term nature of these obligations, and the importance of the assumptions utilized, Entergy’s estimate of these costs is a critical accounting estimate.

Cost Sensitivity

The following chart reflects the sensitivity of qualified pension cost and qualified projected benefit obligation to changes in certain actuarial assumptions (dollars in thousands):

Actuarial Assumption	Change in Assumption	Impact on 2011 Qualified Pension Cost	Impact on Qualified Projected Benefit Obligation
	Increase/(Decrease)

Discount rate	(0.25%)	$1,542	$18,452
Rate of return on plan assets	(0.25%)	$981	-
Rate of increase in compensation	0.25%	$625	$3,439

The following chart reflects the sensitivity of postretirement benefit cost and accumulated postretirement benefit obligation to changes in certain actuarial assumptions (dollars in thousands):

Actuarial Assumption	Change in Assumption	Impact on 2011 Postretirement Benefit Cost	Impact on Accumulated Postretirement Benefit Obligation
	Increase/(Decrease)

Health care cost trend	0.25%	$990	$6,253
Discount rate	(0.25%)	$697	$7,114

Each fluctuation above assumes that the other components of the calculation are held constant.

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Entergy Gulf States Louisiana, L.L.C.

Management’s Financial Discussion and Analysis

Costs and Funding

Total qualified pension cost for Entergy Gulf States Louisiana in 2011 was $9.4 million. Entergy Gulf States Louisiana anticipates 2012 qualified pension cost to be $19.8 million. Entergy Gulf States Louisiana contributed $27.3 million to its pension plans in 2011 and estimates 2012 pension contributions to be approximately $10.8 million; although the required pension contributions will not be known with more certainty until the January 1, 2012 valuations are completed by April 1, 2012.

Total postretirement health care and life insurance benefit costs for Entergy Gulf States Louisiana in 2011 were $16.8 million, including $3.9 million in savings due to the estimated effect of future Medicare Part D subsidies. Entergy Gulf States Louisiana expects 2012 postretirement health care and life insurance benefit costs to approximate $21.3 million, including $3.7 million in savings due to the estimated effect of future Medicare Part D subsidies. Entergy Gulf States Louisiana expects to contribute approximately $8.3 million to its other postretirement plans in 2012.

Federal Healthcare Legislation

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Entergy Corporation and Subsidiaries Management’s Discussion and Analysis.

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Members of

Entergy Gulf States Louisiana, L.L.C.

Baton Rouge, Louisiana

We have audited the accompanying balance sheets of Entergy Gulf States Louisiana, L.L.C. (the “Company”) as of December 31, 2011 and 2010, and the related income statements, statements of comprehensive income, statements of cash flows, and statements of changes in equity (pages 295 through 300 and applicable items in pages 53 through 194) for each of the three years in the period ended December 31, 2011. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

In our opinion, such financial statements present fairly, in all material respects, the financial position of Entergy Gulf States Louisiana, L.L.C. as of December 31, 2011 and 2010, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2011, in conformity with accounting principles generally accepted in the United States of America.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 27, 2012 expressed an unqualified opinion on the Company’s internal control over financial reporting.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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ENTERGY GULF STATES LOUISIANA, L.L.C.
INCOME STATEMENTS

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands)

OPERATING REVENUES
Electric	$	2,069,548		$	2,015,710		$	1,776,610
Natural gas		64,861			81,311			67,776
TOTAL		2,134,409			2,097,021			1,844,386

OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale		437,301			312,960			251,393
Purchased power		780,711			851,694			732,943
Nuclear refueling outage expenses		18,227			24,046			21,787
Other operation and maintenance		351,070			361,329			332,450
Decommissioning		14,189			13,400			13,591
Taxes other than income taxes		75,858			77,519			67,559
Depreciation and amortization		143,387			132,714			135,489
Other regulatory credits - net		(17,045	)		(1,248	)		(1,261	)
TOTAL		1,803,698			1,772,414			1,553,951

OPERATING INCOME		330,711			324,607			290,435

OTHER INCOME
Allowance for equity funds used during construction		9,094			5,513			5,426
Interest and investment income		40,945			42,293			69,951
Miscellaneous - net		(8,799	)		(8,016	)		(8,764	)
TOTAL		41,240			39,790			66,613

INTEREST EXPENSE
Interest expense		84,356			101,318			118,243
Allowance for borrowed funds used during construction		(3,745	)		(3,537	)		(3,427	)
TOTAL		80,611			97,781			114,816

INCOME BEFORE INCOME TAXES		291,340			266,616			242,232

Income taxes		88,313			75,878			89,185

NET INCOME		203,027			190,738			153,047

Preferred distribution requirements and other		825			827			825

EARNINGS APPLICABLE TO
COMMON EQUITY	$	202,202		$	189,911		$	152,222

See Notes to Financial Statements.

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ENTERGY GULF STATES LOUISIANA, L.L.C.
STATEMENTS OF COMPREHENSIVE INCOME

	For the Years Ended December 31,
	2011			2010		2009
	(In Thousands)

Net Income	$	203,027		$	190,738	$	153,047
Other comprehensive income (loss)
Pension and other postretirement liabilities
(net of tax benefit of $16,556, $340, and $13,111)		(29,306	)		1,867		(11,906	)
Other comprehensive income (loss)		(29,306	)		1,867		(11,906	)
Comprehensive Income	$	173,721		$	192,605	$	141,141



See Notes to Financial Statements.

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ENTERGY GULF STATES LOUISIANA, L.L.C.
STATEMENTS OF CASH FLOWS

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands)

OPERATING ACTIVITIES
Net income	$	203,027		$	190,738		$	153,047
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		207,753			194,265			149,080
Deferred income taxes, investment tax credits, and non-current taxes accrued		(6,268	)		87,920			138,817
Changes in working capital:
Receivables		(82,221	)		(30,732	)		177,628
Fuel inventory		2,578			3,471			4,453
Accounts payable		(58,981	)		80,874			(131,603	)
Prepaid taxes and taxes accrued		148,313			(8,176	)		(418	)
Interest accrued		(1,177	)		537			(5,403	)
Deferred fuel costs		74,877			(20,050	)		(49,625	)
Other working capital accounts		(4,600	)		13,068			(116,816	)
Changes in provisions for estimated losses		1,353			83,011			773
Changes in other regulatory assets		(80,027	)		114,528			(44,612	)
Changes in pension and other postretirement liabilities		112,736			(14,041	)		46,083
Other		(35,248	)		30,717			(86,474	)
Net cash flow provided by operating activities		482,115			726,130			234,930

INVESTING ACTIVITIES
Construction expenditures		(219,307	)		(237,251	)		(199,283	)
Allowance for equity funds used during construction		9,094			5,513			5,426
Insurance proceeds		-			2,243			2,180
Nuclear fuel purchases		(87,901	)		(47,785	)		(44,529	)
Proceeds from sale of nuclear fuel		9,647			-			72,843
Payment for purchase of plant		-			-			(74,818	)
Investment in affiliates		-			(150,264	)		160
Payment to storm reserve escrow account		(124	)		(90,073	)		-
Proceeds from nuclear decommissioning trust fund sales		76,844			100,825			95,244
Investment in nuclear decommissioning trust funds		(94,922	)		(115,055	)		(105,167	)
Change in money pool receivable - net		39,407			(12,872	)		(38,542	)
Changes in other investments - net		-			3,136			-
Net cash flow used in investing activities		(267,262	)		(541,583	)		(286,486	)

FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		-			306,234			297,199
Retirement of long-term debt		(47,340	)		(344,841	)		(118,961	)
Changes in credit borrowings - net		5,200			(10,100	)		-
Dividends/distributions paid:
Common equity		(301,950	)		(124,300	)		(30,700	)
Preferred membership interests		(825	)		(827	)		(825	)
Other		(266	)		-			-
Net cash flow provided by (used in) financing activities		(345,181	)		(173,834	)		146,713

Net increase (decrease) in cash and cash equivalents		(130,328	)		10,713			95,157

Cash and cash equivalents at beginning of period		155,173			144,460			49,303

Cash and cash equivalents at end of period	$	24,845		$	155,173		$	144,460

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid/(received) during the period for:
Interest - net of amount capitalized	$	82,413		$	97,803		$	120,655
Income taxes	$	(56,289	)	$	(16,803	)	$	60,594

Noncash financing activities:
Repayment by Entergy Texas of assumed long-term debt	$	-		$	167,742		$	602,229

See Notes to Financial Statements.

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ENTERGY GULF STATES LOUISIANA, L.L.C.
BALANCE SHEETS
ASSETS

	December 31,
	2011			2010
	(In Thousands)

CURRENT ASSETS
Cash and cash equivalents:
Cash	$	217		$	231
Temporary cash investments		24,628			154,942
Total cash and cash equivalents		24,845			155,173
Accounts receivable:
Customer		61,648			60,369
Allowance for doubtful accounts		(843	)		(1,306	)
Associated companies		171,431			119,252
Other		22,082			27,728
Accrued unbilled revenues		51,155			56,616
Total accounts receivable		305,473			262,659
Fuel inventory - at average cost		23,249			25,827
Materials and supplies - at average cost		114,075			113,302
Deferred nuclear refueling outage costs		21,066			7,372
Prepaid taxes		-			40,946
Prepayments and other		5,180			5,127
TOTAL		493,888			610,406

OTHER PROPERTY AND INVESTMENTS
Investment in affiliate preferred membership interests		339,664			339,664
Decommissioning trust funds		420,917			393,580
Non-utility property - at cost (less accumulated depreciation)		164,712			156,845
Storm reserve escrow account		90,249			90,125
Other		12,701			12,011
TOTAL		1,028,243			992,225

UTILITY PLANT
Electric		7,068,657			6,907,268
Natural gas		129,950			124,020
Construction work in progress		122,051			119,017
Nuclear fuel		206,031			202,609
TOTAL UTILITY PLANT		7,526,689			7,352,914
Less - accumulated depreciation and amortization		3,906,353			3,812,394
UTILITY PLANT - NET		3,620,336			3,540,520

DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Regulatory asset for income taxes - net		249,058			234,406
Other regulatory assets		333,898			270,883
Deferred fuel costs		100,124			100,124
Other		13,506			14,832
TOTAL		696,586			620,245

TOTAL ASSETS	$	5,839,053		$	5,763,396

See Notes to Financial Statements.

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ENTERGY GULF STATES LOUISIANA, L.L.C.
BALANCE SHEETS
LIABILITIES AND EQUITY

	December 31,
	2011			2010
	(In Thousands)

CURRENT LIABILITIES
Currently maturing long-term debt	$	60,000		$	-
Accounts payable:
Associated companies		73,305			71,601
Other		101,009			160,246
Customer deposits		49,734			48,631
Taxes accrued		107,367			-
Accumulated deferred income taxes		5,427			1,749
Interest accrued		26,084			27,261
Deferred fuel costs		97,178			22,301
Pension and other postretirement liabilities		7,911			7,415
Gas hedge contracts		8,572			1,034
Other		15,294			14,015
TOTAL		551,881			354,253

NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued		1,397,230			1,405,374
Accumulated deferred investment tax credits		81,520			84,858
Other regulatory liabilities		75,721			83,479
Decommissioning and asset retirement cost liabilities		359,792			339,925
Accumulated provisions		99,033			97,680
Pension and other postretirement liabilities		332,672			220,432
Long-term debt		1,482,430			1,584,332
Long-term payables - associated companies		31,254			32,596
Other		47,397			51,254
TOTAL		3,907,049			3,899,930

Commitments and Contingencies

EQUITY
Preferred membership interests without sinking fund		10,000			10,000
Member's equity		1,439,733			1,539,517
Accumulated other comprehensive loss		(69,610	)		(40,304	)
TOTAL		1,380,123			1,509,213

TOTAL LIABILITIES AND EQUITY	$	5,839,053		$	5,763,396

See Notes to Financial Statements.

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ENTERGY GULF STATES LOUISIANA, L.L.C.
STATEMENTS OF CHANGES IN EQUITY
For the Years Ended December 31, 2011, 2010, and 2009

			Common Equity
	Preferred Membership Interests		Member's Equity			Accumulated Other Comprehensive Income (Loss)			Total
	(In Thousands)

Balance at December 31, 2008	$	10,000	$	1,352,408		$	(30,265	)	$	1,332,143
Net income		-		153,047			-			153,047
Other comprehensive loss		-		-			(11,906	)		(11,906	)
Dividends/distributions declared on common equity		-		(30,700	)		-			(30,700	)
Dividends/distributions declared on preferred membership interests		-		(825	)		-			(825	)
Balance at December 31, 2009	$	10,000	$	1,473,930		$	(42,171	)	$	1,441,759
Net income		-		190,738			-			190,738
Other comprehensive income		-		-			1,867			1,867
Dividends/distributions declared on common equity		-		(124,300	)		-			(124,300	)
Dividends/distributions declared on preferred membership interests		-		(827	)		-			(827	)
Other		-		(24	)		-			(24	)
Balance at December 31, 2010	$	10,000	$	1,539,517		$	(40,304	)	$	1,509,213
Net income		-		203,027			-			203,027
Other comprehensive loss		-		-			(29,306	)		(29,306	)
Dividends/distributions declared on common equity		-		(301,950	)		-			(301,950	)
Dividends/distributions declared on preferred membership interests		-		(825	)		-			(825	)
Other		-		(36	)		-			(36	)
Balance at December 31, 2011	$	10,000	$	1,439,733		$	(69,610	)	$	1,380,123

See Notes to Financial Statements.

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ENTERGY GULF STATES LOUISIANA, L.L.C.
SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON

	2011		2010		2009		2008		2007
	(In Thousands)

Operating revenues (2)	$	2,134,409	$	2,097,021	$	1,844,386	$	2,733,365	$	3,534,612
Net Income (2)	$	203,027	$	190,738	$	153,047	$	144,767	$	192,779
Total assets	$	5,839,053	$	5,763,396	$	5,569,083	$	6,056,961	$	6,072,691
Long-term obligations (1)	$	1,482,430	$	1,584,332	$	1,740,592	$	1,944,180	$	1,756,087


		2011		2010		2009		2008		2007
	(Dollars In Millions)
Electric Operating Revenues (2):
Residential	$	479	$	498	$	393	$	554	$	1,042
Commercial		416		426		354		520		817
Industrial		490		489		383		672		1,035
Governmental		22		21		18		25		45
Total retail		1,407		1,434		1,148		1,771		2,939
Sales for resale:
Associated companies		562		463		475		643		233
Non-associated companies		52		79		105		181		196
Other		49		40		49		38		80
Total	$	2,070	$	2,016	$	1,777	$	2,633	$	3,448
Billed Electric Energy Sales (GWh) (2):
Residential		5,383		5,538		5,090		4,888		10,215
Commercial		5,239		5,274		5,058		4,973		8,980
Industrial		9,041		8,801		7,601		8,416		15,012
Governmental		222		210		213		215		448
Total retail		19,885		19,823		17,962		18,492		34,655
Sales for resale:
Associated companies		8,595		8,516		7,084		6,490		2,488
Non-associated companies		1,013		1,705		2,546		2,524		2,900
Total		29,493		30,044		27,592		27,506		40,043

(1) Includes long-term debt (excluding currently maturing debt) and noncurrent capital lease obligations.
(2) Entergy Gulf States Louisiana's income statements for the years ended December 31, 2008, 2009, 2010, and 2011 reflect the effects of the separation of the Texas business. Entergy Gulf States Louisiana's income statements for the year ended December 31, 2007 include the operations of Entergy Texas.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Plan to Spin Off the Utility’s Transmission Business

Results of Operations

Net Income

2011 Compared to 2010

Net income increased $242.5 million primarily due to a settlement with the IRS related to the mark-to-market income tax treatment of power purchase contracts, which resulted in a $422 million income tax benefit. The net income effect was partially offset by a $199 million regulatory charge, which reduced net revenue, because a portion of the benefit will be shared with customers. See Note 3 to the financial statements for additional discussion of the settlement and benefit sharing.

2010 Compared to 2009

Net income decreased slightly by $1.4 million primarily due to higher other operation and maintenance expenses, a higher effective income tax rate, and higher interest expense, almost entirely offset by higher net revenue.

Net Revenue

2011 Compared to 2010

		Amount
		(In Millions)

2010 net revenue		$1,043.7
Mark-to-market tax settlement sharing		(195.9)
Retail electric price		32.5
Volume/weather		11.6
Other		(5.7)
2011 net revenue		$886.2

The retail electric price variance is primarily due to a formula rate plan increase effective May 2011. See Note 2 to the financial statements for discussion of the formula rate plan increase.

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The volume/weather variance is primarily due to an increase of 1,095 GWh, or 4%, in billed electricity usage. Usage in the industrial sector increased primarily as a result of increased consumption by a large customer in the chemical industry as the result of a plant expansion. The increase was partially offset by the effect of less favorable weather on residential sales.

Other regulatory charges (credits)

Other regulatory charges increased primarily due to a settlement with the IRS related to the mark-to-market income tax treatment of power purchase contracts because a portion of the settlement will be shared with customers. See Note 3 to the financial statements for additional discussion of the settlement and benefit sharing.

2010 Compared to 2009

		Amount
		(In Millions)

2009 net revenue		$980.0
Volume/weather		52.9
Retail electric price		17.5
Other		(6.7)
2010 net revenue		$1,043.7

The volume/weather variance is primarily due to an increase of 2,253 GWh, or 8%, in billed electricity usage. Usage in the industrial sector increased primarily as a result of increased consumption by a large customer in the petroleum refining industry, as well as increases in the chemical industry. The effect of more favorable weather was the primary driver of the increase in the residential and commercial sales.

The retail electric price variance is primarily due to a net increase in the formula rate plan effective November 2009 which allowed Entergy Louisiana to reset its rates to achieve a 10.25% return on equity for the 2008 test year. See Note 2 to the financial statements for further discussion of settlement and the formula rate plan reset.

Gross operating revenues and fuel and purchased power expenses

Gross operating revenues increased primarily due to:

·	an increase of $200.7 million in fuel cost recovery revenues due to higher fuel rates and increased usage;

·	an increase of $114.9 million in rider revenues primarily due to lower System Agreement credits in 2010; and

·	the increase related to volume/weather, as discussed above.

Fuel and purchased power expenses increased primarily due to an increase in the average market price of purchased power, an increase in demand, and an increase in the recovery from customers of deferred fuel costs, partially offset by a decrease in the average market price of natural gas.

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Other Income Statement Variances

2011 Compared to 2010

Other operation and maintenance expenses increased primarily due to an increase of $17.1 million in transmission investment equalization expenses as a result of a billing adjustment recorded in the fourth quarter 2011 related to prior transmission costs (for the approximate period of 1996-2011) allocable to Entergy Louisiana under the Entergy System Agreement and an increase of $17.5 million in fossil-fueled generation expenses due to an overall higher scope of outages compared to prior year and the addition of Acadia Unit 2 in April 2011.

Other income increased primarily due to an increase of $10.8 million in distributions earned on preferred membership interests purchased from Entergy Holdings Company with the proceeds received from the Act 55 storm cost financing and an increase in the allowance for equity funds used during construction due to more construction work in progress in 2011. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Hurricane Gustav and Hurricane Ike” and Note 2 to the financial statements for a discussion of the Act 55 storm cost financing.

2010 Compared to 2009

Other operation and maintenance expenses increased primarily due to:

an increase of $16.2 million in compensation and benefits costs, resulting from decreasing discount rates, the amortization of benefit trust asset losses, and an increase in the accrual for incentive-based compensation. See Note 11 to the financial statements for further discussion of benefits costs;

·	an increase of $6.4 million in fossil expenses due to higher outage expenses compared to prior year; and

·	an increase of $5.9 million in nuclear expenses due to higher nuclear labor costs.

Interest expense increased primarily due to the issuance of $400 million of 5.40% Series first mortgage bonds in November 2009.

Income Taxes

The effective income tax rates for 2011, 2010, and 2009 were (357)%, 22.3%, and 16.2%, respectively. The decline in the rate for 2011 is primarily due to the reversal in the third quarter 2011 for uncertain tax positions resulting from a settlement with the IRS related to the mark-to-market income tax treatment of power purchase contracts. See Note 3 to the financial statements for a reconciliation of the federal statutory rate of 35.0% to the effective income tax rates for 2009, 2010, and 2011 and for a discussion of the IRS settlement and audits.

Liquidity and Capital Resources

Cash Flow

Cash flows for the years ended December 31, 2011, 2010, and 2009 were as follows:

		2011	2010	2009
		(In Thousands)

Cash and cash equivalents at beginning of period		$123,254	$151,849	$138,918

Cash flow provided by (used in):
	Operating activities	479,342	932,334	87,879
	Investing activities	(811,203)	(861,329)	(436,251)
	Financing activities	209,485	(99,600)	361,303
	Net increase (decrease) in cash and cash equivalents	(122,376)	(28,595)	12,931

Cash and cash equivalents at end of period		$878	$123,254	$151,849

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Operating Activities

Cash flow provided by operating activities decreased $453 million in 2011 primarily due to proceeds of $462 million received in 2010 from the LURC as a result of the Act 55 storm cost financings. The decrease was partially offset by income tax refunds of $39.6 million in 2011 compared to income tax payments of $28.3 million in 2010. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Hurricane Gustav and Hurricane Ike” and Note 2 to the financial statements herein for a discussion of the storm cost financings. In 2011, Entergy Louisiana received tax cash refunds in accordance with the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement. The refunds primarily result from a decrease in 2010 taxable income from what was previously estimated because of the recognition of additional repair expenses for tax purposes associated with a tax accounting change filed in 2010.

Cash flow provided by operating activities increased $844.5 million in 2010 primarily due to proceeds of $462.4 million received from the LURC as a result of the Act 55 storm cost financings, the absence in 2010 of the storm restoration spending that occurred in 2009, a decrease of $195.3 million in income tax payments, and increased recovery of fuel costs due to a higher fuel rate for the period, offset by an increase of $58.5 million in pension contributions. See “Hurricane Gustav and Hurricane Ike” below and Note 2 to the financial statements herein for a discussion of the storm cost financings. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates” below for a discussion of qualified pension and other postretirement benefits. In 2010, Entergy Louisiana made tax payments in accordance with the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement. The payments resulted from the reversal of temporary differences for which Entergy Louisiana previously received cash tax benefits and from estimated federal income tax payments for tax year 2010.

Investing Activities

Net cash flow used in investing activities decreased $50.1 million in 2011 primarily due to:

the investment in 2010 of $262.4 million in affiliate securities and the investment of $200 million in the storm reserve escrow account as a result of the Act 55 storm cost financings. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Gustav and Hurricane Ike” and Note 2 to the financial statements for a discussion of the Act 55 storm cost financing; and

·	money pool activity.

The increase was partially offset by:

·	the purchase of the Acadia Power Plant for approximately $300 million in April 2011; and

an increase in nuclear fuel purchases because of the timing of refueling outages and the purchase of nuclear fuel inventory from System Fuels because the Utility companies will now purchase nuclear fuel throughout the nuclear fuel procurement cycle, rather than purchasing it from System Fuels at the time of refueling.

Decreases in Entergy Louisiana’s receivable from the money pool are a source of cash flow, and Entergy Louisiana’s receivable from the money pool decreased by $49.9 million in 2011 compared to decreasing by $2.9 million in 2010. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Net cash flow used in investing activities increased $425.1 million in 2010 primarily due to the investment in 2010 of $262.4 million in affiliate securities and the investment of $200 million in the storm reserve escrow account as a result of the Act 55 storm cost financings, partially offset by decreased construction expenditures as a result of higher distribution construction expenditures in 2009 due to Hurricane Gustav and decreased fossil construction expenditures due to the suspension of the Little Gypsy repowering project in 2009. The decrease in construction expenditures was partially offset by an increase of $24.9 million in costs associated with the development of new nuclear generation at River Bend, as discussed below, increased nuclear construction expenditures primarily due to the Waterford 3 steam generator replacement project and the dry fuel storage project, and increased transmission construction expenditures primarily due to additional reliability work. See “Hurricane Gustav and Hurricane Ike” below and Note 2 to the financial statements for a discussion of the storm cost financings. See MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - “Little Gypsy Repowering Project” for a discussion of the suspension and subsequent cancellation of the Little Gypsy repowering project.

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Financing Activities

Entergy Louisiana’s financing activities provided cash of $209.5 million in 2011 compared to using cash of $99.6 million in 2010 primarily due to the following cash flow activity:

·	the issuance by Entergy Louisiana Investment Recovery Funding, L.L.C., a wholly owned subsidiary of Entergy Louisiana, of $207.2 million of senior secured investment recovery bonds with a coupon of 2.04% in September 2011;

·	net cash issuances of $200 million of first mortgage bonds in 2011 compared to net cash redemptions of $120 million of first mortgage bonds in 2010;

·	an increase in borrowings on the nuclear fuel company variable interest entity’s credit facility;

·	borrowings of $50 million on its credit facility in 2011;

·	the retirement of the $30 million Series D note by the nuclear fuel company variable interest entity in January 2010;

·	the issuance of the $20 million Series F note by the nuclear fuel company variable interest entity in March 2011; and

·	money pool activity.

The increases were offset by the following:

·	common equity dividends of $358.2 million paid in 2011;

·	the issuance in October 2010 of $115 million of 5% Revenue Bonds Series 2010; and

·	a principal payment of $35.5 million in 2011 for the Waterford 3 sale-leaseback obligation compared to a principal payment of $17.3 million in 2010.

Increases in Entergy Louisiana’s payable to the money pool are a source of cash flow, and Entergy Louisiana’s payable to the money pool increased by $118.4 million in 2011.

Entergy Louisiana’s financing activities used $99.6 million in 2010 compared to providing $361.3 million in 2009. The following cash flow activity occurred:

·	net cash redemptions of $120 million of first mortgage bonds in 2010;

·	the retirement in January 2010 of the $30 million Series D note by the nuclear fuel company variable interest entity;

·	the issuance in October 2010 of $115 million of 5% Revenue Bonds Series 2010;

·	the payment on credit borrowings of $24.1 million by the nuclear fuel company variable interest entity;

·	$20.6 million in common equity distributions in 2009; and

·	a principal payment of $17.3 million in 2010 for the Waterford 3 sale-leaseback obligation compared to a principal payment of $6.6 million in 2009.

See Note 5 to the financial statements for details of long-term debt.

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Capital Structure

Entergy Louisiana’s capitalization is balanced between equity and debt, as shown in the following table.

	December 31, 2011	December 31, 2010

Debt to capital	47.1%	46.1%
Effect of excluding securitization bonds	(2.4)%	0.0%
Debt to capital, excluding securitization bonds (1)	44.7%	46.1%
Effect of subtracting cash	0.0%	(1.7)%
Net debt to net capital, excluding securitization bonds (1)	44.7%	44.4%

(1)	Calculation excludes the securitization bonds, which are non-recourse to Entergy Louisiana.

Net debt consists of debt less cash and cash equivalents. Debt consists of notes payable, capital lease obligations, and long-term debt, including the currently maturing portion. Capital consists of debt and members’ equity. Net capital consists of capital less cash and cash equivalents. Entergy Louisiana uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Louisiana’s financial condition.

Uses of Capital

Entergy Louisiana requires capital resources for:

·	construction and other capital investments;

·	debt and preferred equity maturities or retirements;

·	working capital purposes, including the financing of fuel and purchased power costs; and

·	distribution and interest payments.

Following are the amounts of Entergy Louisiana’s planned construction and other capital investments, existing debt and lease obligations (includes estimated interest payments), and other purchase obligations:

	2012	2013-2014	2015-2016	After 2016	Total
	(In Millions)
Planned construction and capital investment (1):
Generation	$487	$659	N/A	N/A	$1,146
Transmission	108	185	N/A	N/A	293
Distribution	105	265	N/A	N/A	370
Other	12	31	N/A	N/A	43
Total	$712	$1,140	N/A	N/A	$1,852
Long-term debt (2)	$193	$314	$268	$3,084	$3,859
Operating leases	$9	$14	$8	$2	$33
Purchase obligations (3)	$609	$720	$705	$3,820	$5,854

(1)	Includes approximately $217 million annually for maintenance capital, which is planned spending on routine capital projects that are necessary to support reliability of service, equipment or systems and to support normal customer growth.
(2)	Includes estimated interest payments. Long-term debt is discussed in Note 5 to the financial statements.
(3)	Purchase obligations represent the minimum purchase obligation or cancellation charge for contractual obligations to purchase goods or services. For Entergy Louisiana, almost all of the total consists of unconditional fuel and purchased power obligations, including its obligations under the Vidalia purchased power agreement and the Unit Power Sales Agreement, both of which are discussed in Note 8 to the financial statements.

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In addition to the contractual obligations given above, Entergy Louisiana currently expects to contribute approximately $23.8 million to its pension plans and approximately $10 million to other postretirement plans in 2012 although the required pension contributions will not be known with more certainty until the January 1, 2012 valuations are completed by April 1, 2012.

Also in addition to the contractual obligations, Entergy Louisiana has $229.5 million of unrecognized tax benefits and interest net of unused tax attributes for which the timing of payments beyond 12 months cannot be reasonably estimated due to uncertainties in the timing of effective settlement of tax positions. See Note 3 to the financial statements for additional information regarding unrecognized tax benefits.

The planned capital investment estimate for Entergy Louisiana reflects capital required to support existing business and customer growth, including the replacement of the Waterford 3 steam generators and the Ninemile 6 self-build project, both of which are discussed below. Entergy’s Utility supply plan initiative will continue to seek to transform its generation portfolio with new or repowered generation resources. Opportunities resulting from the supply plan initiative, including new projects or the exploration of alternative financing sources, could result in increases or decreases in the capital expenditure estimates given above. The estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints, environmental compliance, market volatility, economic trends, business restructuring, changes in project plans, and the ability to access capital.

Management provides more information on long-term debt maturities in Note 5 to the financial statements.

As an indirect, wholly-owned subsidiary of Entergy Corporation, Entergy Louisiana pays distributions from its earnings at a percentage determined monthly. Entergy Louisiana’s long-term debt indentures contain restrictions on the payment of cash dividends or other distributions on its common and preferred membership interests.

Waterford 3 Steam Generator Replacement Project

Entergy Louisiana planned to replace the Waterford 3 steam generators, along with the reactor vessel closure head and control element drive mechanisms, in the spring 2011. Replacement of these components is common to pressurized water reactors throughout the nuclear industry. In December 2010, Entergy Louisiana advised the LPSC that the replacement generators would not be completed and delivered by the manufacturer in time to install them during the spring 2011 refueling outage. During the final steps in the manufacturing process, the manufacturer discovered separation of stainless steel cladding from the carbon steel base metal in the channel head of both replacement steam generators (RSGs), in areas beneath and adjacent to the divider plate. As a result of this damage, the manufacturer was unable to meet the contractual delivery deadlines, and the RSGs were not installed in the spring 2011. Entergy Louisiana worked with the manufacturer to fully develop and evaluate repair options, and expects the replacement steam generators to be delivered in time for the Fall 2012 refueling outage. Extensive inspections of the existing steam generators at Waterford 3 in cooperation with the manufacturer were completed in April 2011. The review of data obtained during these inspections supports the conclusion that Waterford 3 can operate safely for another full cycle before the replacement of the existing steam generators. Entergy Louisiana has formally reported its findings to the NRC. At this time, a requirement to perform a mid-cycle outage for further inspections in order to allow the plant to continue operation until its Fall 2012 refueling outage is not anticipated. Entergy Louisiana currently expects the cost of the project, including carrying costs, to be approximately $687 million, assuming the replacement occurs during the Fall 2012 refueling outage.

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See State and Local Rate Regulation and Fuel-Cost Recovery below for a discussion of the renewal of Entergy Louisiana’s formula rate plan for the 2011 test year and its provisions addressing the Waterford 3 steam generator replacement project.

Ninemile Point Unit 6 Self-Build Project

New Nuclear Development

Sources of Capital

Entergy Louisiana’s sources to meet its capital requirements include:

·	internally generated funds;

·	cash on hand;

·	debt or preferred membership interest issuances; and

·	bank financing under new and existing facilities.

Entergy Louisiana may refinance, redeem, or otherwise retire debt and preferred membership interests prior to maturity, to the extent market conditions and interest and distribution rates are favorable.

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All debt and common and preferred membership interest issuances by Entergy Louisiana require prior regulatory approval. Preferred membership interest and debt issuances are also subject to issuance tests set forth in its bond indentures and other agreements. Entergy Louisiana has sufficient capacity under these tests to meet its foreseeable capital needs.

Entergy Louisiana’s receivables from or (payables to) the money pool were as follows as of December 31 for each of the following years:

2011	2010	2009	2008
(In Thousands)

($118,415)	$49,887	$52,807	$61,236

See Note 4 to the financial statements for a description of the money pool.

Entergy Louisiana has a credit facility in the amount of $200 million scheduled to expire in August 2012. As of December 31, 2011, $50 million was outstanding on the credit facility.

Entergy Louisiana obtained short-term borrowing authorization from the FERC under which it may borrow through October 2013, up to the aggregate amount, at any one time outstanding, of $250 million. See Note 4 to the financial statements for further discussion of Entergy Louisiana’s short-term borrowing limits. Entergy Louisiana has also obtained an order from the FERC authorizing long-term securities issuances through July 2013.

Little Gypsy Repowering Project

In April 2007, Entergy Louisiana announced that it intended to pursue the solid fuel repowering of a 538 MW unit at its Little Gypsy plant. In March 2009 the LPSC voted in favor of a motion directing Entergy Louisiana to temporarily suspend the repowering project and, based upon an analysis of the project’s economic viability, to make a recommendation regarding whether to proceed with the project. This action was based upon a number of factors including the recent decline in natural gas prices, as well as environmental concerns, the unknown costs of carbon legislation and changes in the capital/financial markets. In April 2009, Entergy Louisiana complied with the LPSC’s directive and recommended that the project be suspended for an extended period of time of three years or more. In May 2009 the LPSC issued an order declaring that Entergy Louisiana’s decision to place the Little Gypsy project into a longer-term suspension of three years or more is in the public interest and prudent.

In October 2009, Entergy Louisiana made a filing with the LPSC seeking permission to cancel the Little Gypsy repowering project and seeking project cost recovery over a five-year period. In June 2010 and August 2010, the LPSC Staff and Intervenors filed testimony. The LPSC Staff (1) agreed that it was prudent to move the project from long-term suspension to cancellation and that the timing of the decision to suspend on a longer-term basis was not imprudent; (2) indicated that, except for $0.8 million in compensation-related costs, the costs incurred should be deemed prudent; (3) recommended recovery from customers over ten years but stated that the LPSC may want to consider 15 years; (4) allowed for recovery of carrying costs and earning a return on project costs, but at a reduced rate approximating the cost of debt, while also acknowledging that the LPSC may consider ordering no return; and (5)

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indicated that Entergy Louisiana should be directed to securitize project costs, if legally feasible and in the public interest. In the third quarter 2010, in accordance with accounting standards, Entergy Louisiana determined that it was probable that the Little Gypsy repowering project would be abandoned and accordingly reclassified $199.8 million of project costs from construction work in progress to a regulatory asset. A hearing on the issues, except for cost allocation among customer classes, was held before the ALJ in November 2010. In January 2011 all parties participated in a mediation on the disputed issues, resulting in a settlement of all disputed issues, including cost recovery and cost allocation. The settlement provides for Entergy Louisiana to recover $200 million as of March 31, 2011, and carrying costs on that amount on specified terms thereafter. The settlement also provides for Entergy Louisiana to recover the approved project costs by securitization. In April 2011, Entergy Louisiana filed an application with the LPSC to authorize the securitization of the investment recovery costs associated with the project and to issue a financing order by which Entergy Louisiana could accomplish such securitization. In August 2011 the LPSC issued an order approving the settlement and also issued a financing order for the securitization. See Note 5 to the financial statements for a discussion of the September 2011 issuance of the securitization bonds.

Hurricane Gustav and Hurricane Ike

In September 2008, Hurricane Gustav (and, to a much lesser extent, Hurricane Ike) caused catastrophic damage to Entergy Louisiana’s service territory. The storms resulted in widespread power outages, significant damage to distribution, transmission, and generation infrastructure, and the loss of sales during the power outages. On October 9, 2008, Entergy Louisiana drew all of its $134 million funded storm reserve. On October 15, 2008, the LPSC approved Entergy Louisiana’s request to defer and accrue carrying costs on unrecovered storm expenditures during the period the company seeks regulatory recovery. The approval was without prejudice to the ultimate resolution of the total amount of prudently incurred storm costs or final carrying costs rate.

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Entergy Louisiana does not report the bonds on its balance sheet because the bonds are the obligation of the LCDA and there is no recourse against Entergy or Entergy Louisiana in the event of a bond default. To service the bonds, Entergy Louisiana collects a system restoration charge on behalf of the LURC, and remits the collections to the bond indenture trustee. Entergy Louisiana does not report the collections as revenue because it is merely acting as the billing and collection agent for the state.

State and Local Rate Regulation and Fuel-Cost Recovery

The rates that Entergy Louisiana charges for its services significantly influence its financial position, results of operations, and liquidity. Entergy Louisiana is regulated and the rates charged to its customers are determined in regulatory proceedings. A governmental agency, the LPSC, is primarily responsible for approval of the rates charged to customers.

In May 2005 the LPSC approved a rate filing settlement that included the adoption of a three-year formula rate plan, the terms of which included an ROE mid-point of 10.25% for the initial three-year term of the plan and permit Entergy Louisiana to recover incremental capacity costs outside of a traditional base rate proceeding. Under the formula rate plan, over- and under-earnings outside an allowed regulatory range of 9.45% to 11.05% will be allocated 60% to customers and 40% to Entergy Louisiana. The initial formula rate plan filing was made in May 2006. As discussed below the formula rate plan has been extended, with return on common equity provisions consistent with previously approved provisions, to cover the 2008, 2009, 2010, and 2011 test years.

In October 2009 the LPSC approved a settlement that resolved Entergy Louisiana’s 2006 and 2007 test year filings provided for a new formula rate plan for the 2008, 2009, and 2010 test years. 10.25% is the target midpoint return on equity for the new formula rate plan, with an earnings bandwidth of +/- 80 basis points (9.45% - 11.05%). Entergy Louisiana was permitted, effective with the November 2009 billing cycle, to reset its rates to achieve a 10.25% return on equity for the 2008 test year. The rate reset, a $2.5 million increase that included a $16.3 million cost of service adjustment less a $13.8 million net reduction for decreased capacity costs and a base rate reclassification, was implemented for the November 2009 billing cycle, and the rate reset was subject to refund pending review of the 2008 test year filing that was made in October 2009. In April 2010, Entergy Louisiana and the LPSC staff submitted a joint report on the 2008 test year filing and requested that the LPSC accept the report, which resulted in a $0.1 million reduction in rates effective in the May 2010 billing cycle and a $0.1 million refund. In addition, Entergy Louisiana moved the recovery of approximately $12.5 million of capacity costs from fuel adjustment clause recovery to base rate recovery. At its April 21, 2010 meeting, the LPSC accepted the joint report.

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In November 2011 the LPSC approved a one-year extension of Entergy Louisiana’s current formula rate plan. The next formula rate plan filing, for the 2011 test year, will be made in May 2012 and will include a separate identification of any operating and maintenance expense savings that are expected to occur once the Waterford 3 steam generator replacement project is complete. Pursuant to the LPSC decision, from September 2012 through December 2012 earnings above an 11.05% return on common equity (based on the 2011 test year) would be accrued and used to offset the Waterford 3 replacement steam generator revenue requirement for the first twelve months that the unit is in rates. If the project is not in service by January 1, 2013, earnings above a 10.25% return on common equity (based on the 2011 test year) for the period January 1, 2013 through the date that the project is placed in service will be accrued and used to offset the incremental revenue requirement for the first twelve months that the unit is in rates. Upon the in-service date of the replacement steam generators, rates will increase, subject to refund following any prudence review, by the full revenue requirement associated with the replacement steam generators, less (i) the previously accrued excess earnings from September 2012 until the in-service date and (ii) any earnings above a 10.25% return on common equity (based on the 2011 test year) for the period following the in-service date, provided that the excess earnings accrued prior to the in-service date shall only offset the revenue requirement for the first year of operation of the replacement steam generators. These rates are anticipated to remain in effect until Entergy Louisiana’s next full rate case is resolved. Entergy Louisiana is required to file a full rate case by January 2013, if the LPSC has not acted to deny the requested transmission change-of-control to the MISO RTO. If the LPSC has denied this request, then the rate case must be filed by September 30, 2012.

In April 2010, the LPSC authorized its staff to initiate an audit of Entergy Louisiana's fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009. Discovery is in progress, but a procedural schedule has not been established.

In August 2000, the LPSC authorized its staff to initiate a proceeding to audit the fuel adjustment clause filings of Entergy Louisiana. The time period that is the subject of the audit was January 1, 2000 through December 31, 2001. The scope of this docket was expanded to include a review of annual reports on fuel and purchased power transactions with affiliates and a prudence review of transmission planning issues and to include the years 2002 through 2004. Hearings were held and in May 2008 the ALJ issued a final recommendation that found in Entergy Louisiana’s favor on the issues, except for the disallowance of hypothetical SO2 allowance costs included in affiliate purchases. The ALJ recommended a refund of the SO2 allowance costs collected to date and a realignment of these costs into base rates prospectively with an amortization of the refunded amount through base rates over a five-year period. The LPSC issued an order in December 2008 affirming the ALJ’s recommendation. Entergy Louisiana recorded a provision for the disallowance, including interest, and refunded approximately $7 million to customers in 2009.

Industrial and Commercial Customers

Entergy Louisiana’s large industrial and commercial customers continually explore ways to reduce their energy costs. In particular, cogeneration is an option available to a portion of Entergy Louisiana’s industrial customer base. Entergy Louisiana responds by working with industrial and commercial customers and negotiating electric service contracts to provide competitive rates that match specific customer needs and load profiles. Entergy Louisiana actively participates in economic development, customer retention, and reclamation activities to increase industrial and commercial demand, from both new and existing customers. Entergy Louisiana does not currently expect additional significant losses to cogeneration because of the current economics of the electricity markets and Entergy Louisiana’s marketing efforts in retaining industrial customers.

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Federal Regulation

Nuclear Matters

Entergy Louisiana owns and, through an affiliate, operates the Waterford 3 nuclear power plant. Entergy Louisiana is, therefore, subject to the risks related to owning and operating a nuclear plant. These include risks from the use, storage, handling and disposal of high-level and low-level radioactive materials, regulatory requirement changes, including changes resulting from events at other plants, limitations on the amounts and types of insurance commercially available for losses in connection with nuclear operations, and technological and financial uncertainties related to decommissioning nuclear plants at the end of their licensed lives, including the sufficiency of funds in decommissioning trusts. In the event of an unanticipated early shutdown of Waterford 3, Entergy Louisiana may be required to provide additional funds or credit support to satisfy regulatory requirements for decommissioning.

Environmental Risks

Entergy Louisiana’s facilities and operations are subject to regulation by various governmental authorities having jurisdiction over air quality, water quality, control of toxic substances and hazardous and solid wastes, and other environmental matters. Management believes that Entergy Louisiana is in substantial compliance with environmental regulations currently applicable to its facilities and operations. Because environmental regulations are subject to change, future compliance costs cannot be precisely estimated.

Critical Accounting Estimates

The preparation of Entergy Louisiana’s financial statements in conformity with generally accepted accounting principles requires management to apply appropriate accounting policies and to make estimates and judgments that can have a significant effect on reported financial position, results of operations, and cash flows. Management has identified the following accounting policies and estimates as critical because they are based on assumptions and measurements that involve a high degree of uncertainty, and the potential for future changes in the assumptions and measurements that could produce estimates that would have a material effect on the presentation of Entergy Louisiana’s financial position or results of operations.

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Nuclear Decommissioning Costs

Unbilled Revenue

As discussed in Note 1 to the financial statements, Entergy Louisiana records an estimate of the revenues earned for energy delivered since the latest customer billing. Each month the estimated unbilled revenue amounts are recorded as revenue and a receivable, and the prior month’s estimate is reversed. The difference between the estimate of the unbilled receivable at the beginning of the period and the end of the period is the amount of unbilled revenue recognized during the period. The estimate recorded is primarily based upon an estimate of customer usage during the unbilled period and the billed price to customers in that month. Therefore, revenue recognized may be affected by the estimated price and usage at the beginning and end of each period, in addition to changes in certain components of the calculation.

Qualified Pension and Other Postretirement Benefits

Cost Sensitivity

The following chart reflects the sensitivity of qualified pension cost and qualified projected benefit obligation to changes in certain actuarial assumptions (dollars in thousands):

Actuarial Assumption	Change in Assumption	Impact on 2011 Qualified Pension Cost	Impact on Projected Qualified Benefit Obligation
	Increase/(Decrease)

Discount rate	(0.25%)	$1,989	$24,591
Rate of return on plan assets	(0.25%)	$1,143	-
Rate of increase in compensation	0.25%	$848	$4,931

The following chart reflects the sensitivity of postretirement benefit cost and accumulated postretirement benefit obligation to changes in certain actuarial assumptions (dollars in thousands):

Actuarial Assumption	Change in Assumption	Impact on 2011 Postretirement Benefit Cost	Impact on Accumulated Postretirement Benefit Obligation
	Increase/(Decrease)

Health care cost trend	0.25%	$984	$5,801
Discount rate	(0.25%)	$720	$6,995

Each fluctuation above assumes that the other components of the calculation are held constant.

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Entergy Louisiana, LLC and Subsidiaries

Management’s Financial Discussion and Analysis

Costs and Funding

Total qualified pension cost for Entergy Louisiana in 2011 was $23.6 million. Entergy Louisiana anticipates 2012 qualified pension cost to be $37.4 million. Entergy Louisiana contributed $60.6 million to its pension plans in 2011 and anticipates funding approximately $23.8 million in 2012 although the required pension contributions will not be known with more certainty until the January 1, 2012 valuations are completed by April 1, 2012.

Total postretirement health care and life insurance benefit costs for Entergy Louisiana in 2011 were $18.2 million, including $3.9 million in savings due to the estimated effect of future Medicare Part D subsidies. Entergy Louisiana expects 2012 postretirement health care and life insurance benefit costs to approximate $22.1 million, including $3.6 million in savings due to the estimated effect of future Medicare Part D subsidies. Entergy Louisiana expects to contribute approximately $10 million to its other postretirement plans in 2012.

Federal Healthcare Legislation

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Entergy Corporation and Subsidiaries Management’s Discussion and Analysis.

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Members of

Entergy Louisiana, LLC and Subsidiaries

Baton Rouge, Louisiana

We have audited the accompanying consolidated balance sheets of Entergy Louisiana, LLC and Subsidiaries (the “Company”) as of December 31, 2011 and 2010 and the related consolidated income statements, consolidated statements of comprehensive income, consolidated statements of cash flows, and consolidated statements of changes in equity (pages 319 through 324 and applicable items in pages 53 through 194) for each of the three years in the period ended December 31, 2011. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

In our opinion, such financial statements present fairly, in all material respects, the financial position of Entergy Louisiana, LLC and Subsidiaries as of December 31, 2011 and 2010, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2011, in conformity with accounting principles generally accepted in the United States of America.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands)

OPERATING REVENUES
Electric	$	2,508,915		$	2,538,766		$	2,183,586

OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale		596,808			667,744			428,904
Purchased power		843,099			847,464			782,235
Nuclear refueling outage expenses		27,903			24,955			21,895
Other operation and maintenance		470,783			432,341			401,898
Decommissioning		24,658			22,960			21,377
Taxes other than income taxes		69,769			68,687			66,627
Depreciation and amortization		206,986			198,133			203,791
Other regulatory charges (credits) - net		182,800			(20,192	)		(7,561	)
TOTAL		2,422,806			2,242,092			1,919,166

OPERATING INCOME		86,109			296,674			264,420

OTHER INCOME
Allowance for equity funds used during construction		33,033			26,875			27,990
Interest and investment income		87,487			80,007			75,522
Miscellaneous - net		(3,520	)		(4,043	)		(4,425	)
TOTAL		117,000			102,839			99,087

INTEREST EXPENSE
Interest expense		116,803			119,484			103,671
Allowance for borrowed funds used during construction		(17,406	)		(17,952	)		(18,059	)
TOTAL		99,397			101,532			85,612

INCOME BEFORE INCOME TAXES		103,712			297,981			277,895

Income taxes (benefit)		(370,211	)		66,546			45,050

NET INCOME		473,923			231,435			232,845

Preferred distribution requirements and other		6,950			6,950			6,950

EARNINGS APPLICABLE TO
COMMON EQUITY	$	466,973		$	224,485		$	225,895


See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

	For the Years Ended December 31,
	2011			2010		2009
	(In Thousands)

Net Income	$	473,923		$	231,435	$	232,845
Other comprehensive income (loss)
Pension and other postretirement liabilities
(net of tax benefit of $7,363, $1,818, and $1,692)		(14,545	)		577		(1,324	)
Other comprehensive income (loss)		(14,545	)		577		(1,324	)
Comprehensive Income	$	459,378		$	232,012	$	231,521


See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands)

OPERATING ACTIVITIES
Net income	$	473,923		$	231,435		$	232,845
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		288,459			285,330			225,168
Deferred income taxes, investment tax credits, and non-current taxes accrued		(327,046	)		28,896			(183,872	)
Changes in working capital:
Receivables		(50,014	)		(6,245	)		193,181
Fuel inventory		(23,916	)		-			-
Accounts payable		21,489			86,103			(25,074	)
Prepaid taxes and taxes accrued		56,348			(25,993	)		300
Interest accrued		4,646			(2,991	)		(5,325	)
Deferred fuel costs		7,308			57,594			(89,930	)
Other working capital accounts		34,824			(51,771	)		(168,238	)
Changes in provisions for estimated losses		(10,496	)		203,255			1,455
Changes in other regulatory assets		(95,909	)		150,952			(84,503	)
Changes in pension and other postretirement liabilities		114,489			49,378			13,664
Other		(14,763	)		(73,609	)		(21,792	)
Net cash flow provided by operating activities		479,342			932,334			87,879

INVESTING ACTIVITIES
Construction expenditures		(433,876	)		(428,373	)		(467,519	)
Allowance for equity funds used during construction		33,033			26,875			27,990
Insurance proceeds		-			188			153
Nuclear fuel purchases		(155,932	)		(617	)		(93,272	)
Proceeds from the sale of nuclear fuel		11,570			-			93,672
Payment for purchase of plant		(299,589	)		-			-
Investment in affiliates		-			(262,430	)		160
Payments to storm reserve escrow account		(277	)		(200,166	)		-
Remittances to transition charge account		(5,200	)		-			-
Proceeds from nuclear decommissioning trust fund sales		19,909			44,500			47,520
Investment in nuclear decommissioning trust funds		(30,728	)		(53,579	)		(54,379	)
Change in money pool receivable - net		49,887			2,920			8,429
Changes in other investments - net		-			9,353			995
Net cash flow used in investing activities		(811,203	)		(861,329	)		(436,251	)

FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		1,170,441			498,801			395,450
Retirement of long-term debt		(785,547	)		(567,326	)		(6,597	)
Change in money pool payable - net		118,415			-			-
Changes in credit borrowings - net		71,326			(24,125	)		-
Dividends/distributions paid:
Common equity		(358,200	)		-			(20,600	)
Preferred membership interests		(6,950	)		(6,950	)		(6,950	)
Net cash flow provided by (used in) financing activities		209,485			(99,600	)		361,303

Net increase (decrease) in cash and cash equivalents		(122,376	)		(28,595	)		12,931

Cash and cash equivalents at beginning of period		123,254			151,849			138,918

Cash and cash equivalents at end of period	$	878		$	123,254		$	151,849

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid/(received) during the period for:
Interest - net of amount capitalized	$	108,072		$	118,676		$	105,586
Income taxes	$	(39,555	)	$	28,266		$	223,610


See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS

	December 31,
	2011			2010
	(In Thousands)

CURRENT ASSETS
Cash and cash equivalents:
Cash	$	878		$	708
Temporary cash investments		-			122,546
Total cash and cash equivalents		878			123,254
Securitization recovery trust account		5,200			-
Accounts receivable:
Customer		102,379			85,799
Allowance for doubtful accounts		(1,147	)		(1,961	)
Associated companies		60,661			81,050
Other		10,945			14,594
Accrued unbilled revenues		78,430			71,659
Total accounts receivable		251,268			251,141
Accumulated deferred income taxes		-			7,072
Fuel inventory		23,919			3
Materials and supplies - at average cost		140,561			138,047
Deferred nuclear refueling outage costs		24,197			11,364
Prepaid taxes		-			25,010
Prepayments and other		13,171			10,719
TOTAL		459,194			566,610

OTHER PROPERTY AND INVESTMENTS
Investment in affiliate preferred membership interests		807,424			807,424
Decommissioning trust funds		253,968			240,535
Storm reserve escrow account		201,249			200,972
Non-utility property - at cost (less accumulated depreciation)		760			946
TOTAL		1,263,401			1,249,877

UTILITY PLANT
Electric		7,859,136			7,216,146
Property under capital lease		274,334			264,266
Construction work in progress		559,437			521,172
Nuclear fuel		165,380			134,528
TOTAL UTILITY PLANT		8,858,287			8,136,112
Less - accumulated depreciation and amortization		3,606,706			3,457,190
UTILITY PLANT - NET		5,251,581			4,678,922

DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Regulatory asset for income taxes - net		175,952			235,404
Other regulatory assets (includes securitization property of
$198,445 as of December 31, 2011 and
$- as of December 31, 2010)		814,472			662,746
Deferred fuel costs		67,998			67,998
Other		31,269			26,866
TOTAL		1,089,691			993,014

TOTAL ASSETS	$	8,063,867		$	7,488,423

See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY

	December 31,
	2011			2010
	(In Thousands)

CURRENT LIABILITIES
Currently maturing long-term debt	$	75,309		$	35,550
Short-term borrowings		44,392			23,066
Accounts payable:
Associated companies		218,001			148,528
Other		130,295			140,564
Customer deposits		86,099			84,437
Accumulated deferred income taxes		4,690			-
Taxes accrued		31,338			-
Interest accrued		36,535			31,889
Deferred fuel costs		66,535			59,227
Pension and other postretirement liabilities		9,161			8,632
System agreement cost equalization		36,800			-
Gas hedge contracts		12,397			380
Other		19,278			17,134
TOTAL		770,830			549,407

NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued		1,098,690			1,896,685
Accumulated deferred investment tax credits		73,283			76,453
Other regulatory liabilities		295,542			88,899
Decommissioning		345,834			321,176
Accumulated provisions		213,060			223,556
Pension and other postretirement liabilities		459,685			345,725
Long-term debt (includes securitization bonds of
$207,123 as of December 31, 2011 and
$- as of December 31, 2010)		2,177,003			1,771,566
Other		65,011			78,085
TOTAL		4,728,108			4,802,145

Commitments and Contingencies

EQUITY
Preferred membership interests without sinking fund		100,000			100,000
Member's equity		2,504,436			2,061,833
Accumulated other comprehensive loss		(39,507	)		(24,962	)
TOTAL		2,564,929			2,136,871

TOTAL LIABILITIES AND EQUITY	$	8,063,867		$	7,488,423

See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Years Ended December 31, 2011, 2010, and 2009

			Common Equity
	Preferred Membership Interests		Member's Equity			Accumulated Other Comprehensive Income (Loss)			Total
	(In Thousands)

Balance at December 31, 2008	$	100,000	$	1,632,053		$	(24,215	)	$	1,707,838
Net income		-		232,845			-			232,845
Other comprehensive loss		-		-			(1,324	)		(1,324	)
Dividends/distributions declared on common equity		-		(20,600	)		-			(20,600	)
Dividends/distributions declared on preferred membership interests		-		(6,950	)		-			(6,950	)
Balance at December 31, 2009	$	100,000	$	1,837,348		$	(25,539	)	$	1,911,809
Net income		-		231,435			-			231,435
Other comprehensive income		-		-			577			577
Dividends/distributions declared on preferred membership interests		-		(6,950	)		-			(6,950	)
Balance at December 31, 2010	$	100,000	$	2,061,833		$	(24,962	)	$	2,136,871
Net income		-		473,923			-			473,923
Additional contribution from parent		-		333,830			-			333,830
Other comprehensive loss		-		-			(14,545	)		(14,545	)
Dividends/distributions declared on common equity		-		(358,200	)		-			(358,200	)
Dividends/distributions declared on preferred membership interests		-		(6,950	)		-			(6,950	)
Balance at December 31, 2011	$	100,000	$	2,504,436		$	(39,507	)	$	2,564,929

See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON

	2011		2010		2009		2008		2007
	(In Thousands)

Operating revenues	$	2,508,915	$	2,538,766	$	2,183,586	$	3,051,294	$	2,737,552
Net Income	$	473,923	$	231,435	$	232,845	$	157,543	$	143,337
Total assets	$	8,063,867	$	7,488,423	$	6,861,903	$	6,685,168	$	5,723,121
Long-term obligations (1)	$	2,177,003	$	1,771,566	$	1,622,709	$	1,423,316	$	1,149,478

(1) Includes long-term debt (excluding currently maturing debt) and noncurrent capital lease obligations.

		2011		2010		2009		2008		2007
	(Dollars In Millions)
Electric Operating Revenues:
Residential	$	830	$	840	$	669	$	967	$	854
Commercial		549		543		456		660		578
Industrial		867		817		664		1,062		872
Governmental		42		42		36		51		43
Total retail	$	2,288	$	2,242	$	1,825		2,740		2,347
Sales for resale:
Associated companies		137		220		252		249		310
Non-associated companies		8		5		5		12		8
Other		76		72		102		50		73
Total	$	2,509	$	2,539	$	2,184	$	3,051	$	2,738
Billed Electric Energy Sales (GWh):
Residential		9,303		9,533		8,684		8,487		8,646
Commercial		6,155		6,164		5,867		5,784		5,848
Industrial		15,813		14,473		13,386		13,162		13,209
Governmental		473		479		459		459		446
Total retail (2)		31,744		30,649		28,396		27,892		28,149
Sales for resale:
Associated companies		2,145		2,860		1,513		2,028		2,299
Non-associated companies		185		101		109		205		112
Total		34,074		33,610		30,018		30,125		30,560


(2) 2006 billed electric energy sales includes 96 GWh of billings related to 2005 deliveries that were billed in 2006
because of billing delays following Hurricane Katrina, which results in an increase of 402 GWh in 2006, or 1.5%, and
an increase of 762 GWh in 2007, or 2.8%.

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ENTERGY MISSISSIPPI, INC.

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Plan to Spin Off the Utility’s Transmission Business

Results of Operations

Net Income

2011 Compared to 2010

Net income increased $23.4 million primarily due to a lower effective income tax rate.

2010 Compared to 2009

Net income increased $6.0 million primarily due to higher net revenue and higher other income, partially offset by higher taxes other than income taxes, higher depreciation and amortization expenses, and higher interest expense.

Net Revenue

2011 Compared to 2010

		Amount
		(In Millions)

2010 net revenue		$555.3
Volume/weather		(4.5)
Transmission equalization		4.5
Other		(0.4)
2011 net revenue		$554.9

The volume/weather variance is primarily due to a decrease of 97 GWh in weather-adjusted usage in the residential and commercial sectors and a decrease in sales volume in the unbilled sales period.

The transmission equalization variance is primarily due to the addition in 2011 of transmission investments that are subject to equalization.

Gross operating revenues and fuel and purchased power expenses

Gross operating revenues increased primarily due to an increase of $57.5 million in gross wholesale revenues due to an increase in sales to affiliated customers, partially offset by a decrease of $26.9 million in power management rider revenue.

Fuel and purchased power expenses increased primarily due to an increase in deferred fuel expense as a result of higher fuel revenues due to higher fuel rates, partially offset by a decrease in the average market prices of natural gas and purchased power.

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Entergy Mississippi, Inc.

Management’s Financial Discussion and Analysis

2010 Compared to 2009

		Amount
		(In Millions)

2009 net revenue		$536.7
Volume/weather		18.9
Other		(0.3)
2010 net revenue		$555.3

The volume/weather variance is primarily due to an increase of 1,046 GWh, or 8%, in billed electricity usage in all sectors, primarily due to the effect of more favorable weather on the residential sector.

Gross operating revenues, fuel and purchased power expenses, and other regulatory charges (credits)

Gross operating revenues increased primarily due to an increase of $22 million in power management rider revenue as the result of higher rates, the volume/weather variance discussed above, and an increase in Grand Gulf rider revenue as a result of higher rates and increased usage, offset by a decrease of $23.5 million in fuel cost recovery revenues due to lower fuel rates.

Fuel and purchased power expenses decreased primarily due to a decrease in deferred fuel expense as a result of prior over-collections, offset by an increase in the average market price of purchased power coupled with increased net area demand.

Other regulatory charges increased primarily due to increased recovery of costs associated with the power management recovery rider.

Other Income Statement Variances

2011 Compared to 2010

Other operation and maintenance expenses decreased primarily due to:

·	a $5.4 million decrease in compensation and benefits costs primarily resulting from an increase in the accrual for incentive-based compensation in 2010 and a decrease in stock option expense; and

·	the sale of $4.9 million of surplus oil inventory.

The decrease was partially offset by an increase of $3.9 million in legal expenses due to the deferral in 2010 of certain litigation expenses in accordance with regulatory treatment.

Taxes other than income taxes increased primarily due to an increase in ad valorem taxes due to a higher 2011 assessment as compared to 2010, partially offset by higher capitalized property taxes as compared with prior year.

Depreciation and amortization expenses increased primarily due to an increase in plant in service.

Interest expense decreased primarily due to a revision caused by FERC’s acceptance of a change in the treatment of funds received from independent power producers for transmission interconnection projects.

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Entergy Mississippi, Inc.

Management’s Financial Discussion and Analysis

2010 Compared to 2009

Taxes other than income taxes increased primarily due to an increase in ad valorem taxes as a result of higher millage rates and a higher 2010 assessment as compared to 2009 and an increase in local franchise taxes as a result of higher revenues primarily in the residential and commercial sectors.

Depreciation and amortization expenses increased primarily due to an increase in plant in service.

Other income increased primarily due to an increase in the allowance for equity funds used during construction due to more construction work in progress in 2010, including the new nuclear development project that is discussed below.

Interest expense increased primarily due to the issuance of $150 million of 6.64% Series first mortgage bonds in June 2009.

Income Taxes

The effective income tax rates for 2011, 2010, and 2009 were 20.9%, 37.0%, and 35.3%, respectively. The decline in the rate for 2011 is primarily due to an intercompany settle up for federal income taxes for years prior to 2008 which include an allocation of the tax benefit of Entergy Corporation’s expenses to the subsidiaries generating taxable income for the respective years. Entergy Mississippi received benefits for the effects of various tax positions settled with the IRS pertaining to the 2006/2007 audit. See Note 3 to the financial statements for a reconciliation of the federal statutory rate of 35.0% to the effective income tax rates.

Liquidity and Capital Resources

Cash Flow

Cash flows for the years ended December 31, 2011, 2010, and 2009 were as follows:

		2011	2010	2009
		(In Thousands)

Cash and cash equivalents at beginning of period		$1,216	$91,451	$1,082

Cash flow provided by (used in):
	Operating activities	99,596	120,107	222,018
	Investing activities	(151,830)	(174,096)	(159,473)
	Financing activities	51,034	(36,246)	27,824
	Net increase (decrease) in cash and cash equivalents	(1,200)	(90,235)	90,369

Cash and cash equivalents at end of period		$16	$1,216	$91,451

Operating Activities

Cash flow provided by operating activities decreased $20.5 million in 2011 primarily due to the purchase of $42.6 million of fuel oil inventory from System Fuels because System Fuels will no longer procure fuel oil for the Utility companies. The decrease was partially offset by an increase in the recovery of fuel costs.

Cash flow provided by operating activities decreased $101.9 million in 2010 primarily due to decreased recovery of fuel costs primarily as a result of prior period over-collections and an increase of $27.7 million in pension contributions, offset by a decrease of $7.1 million in income tax payments. See Note 2 to the financial statements for a discussion of Entergy Mississippi’s fuel and purchased power cost recovery mechanism. See “Critical Accounting Estimates” below for further discussion of qualified pension and other postretirement benefits funding. In 2010, Entergy Mississippi received federal tax cash refunds and made state tax cash payments in accordance with the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement. The federal refunds resulted from the 2009 tax return filed in 2010 and the associated true up adjustment which relates primarily to the acceleration of deductions for plant-related expenditures. The state payments result from the allocation of the combined Mississippi tax reflected on the 2009 tax return filed in 2010 and for amended Mississippi returns for 2006-2008 filed in 2010.

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Entergy Mississippi, Inc.

Management’s Financial Discussion and Analysis

Investing Activities

Cash flow used in investing activities decreased $22.3 million in 2011 primarily due to a decrease in construction expenditures because of a $49 million payment in 2010 to a System Energy subsidiary for costs associated with the development of new nuclear generation at Grand Gulf and the repayment by System Fuels of Entergy Mississippi’s $5.5 million investment in System Fuels. The decrease was offset by money pool activity.

Decreases in Entergy Mississippi’s receivable from the money pool are a source of cash flow, and Entergy Mississippi’s receivable from the money pool decreased $31.4 million in 2010. Entergy Mississippi did not have a receivable from the money pool in 2011. The money pool is an inter-company borrowing arrangement designed to reduce Entergy’s subsidiaries’ need for external short-term borrowings.

Cash flow used in investing activities increased $14.6 million in 2010 primarily due to increased construction expenditures resulting from a $49 million payment to a System Energy subsidiary for costs associated with the development of new nuclear generation at Grand Gulf, as discussed below, and increased transmission construction expenditures resulting from additional transmission reliability work in 2010, offset by money pool activity.

Financing Activities

Entergy Mississippi’s financing activities provided $51.0 million of cash in 2011 compared to using $36.2 million of cash in 2010 primarily due to:

·	the issuance of $275 million of first mortgage bonds in 2011 compared to the issuance of $80 million of first mortgage bonds in 2010; and

·	a decrease of $40.1 million in common stock dividends.

The cash provided was partially offset by the redemption of $180 million of first mortgage bonds in 2011 compared to the redemption of $100 million of first mortgage bonds in 2010 and money pool activity.

Decreases in Entergy Mississippi’s payable to the money pool are a use of cash flow, and Entergy Mississippi’s payable to the money pool decreased by $31.3 million in 2011 compared to increasing by $33.3 million in 2010.

Entergy Mississippi’s financing activities used $36.2 million of cash in 2010 compared to providing $27.8 million of cash in 2009 primarily due to:

·	the redemption, prior to maturity, of $100 million of 7.25% Series first mortgage bonds in April 2010;

·	the issuance of $150 million of 6.64% Series first mortgage bonds in June 2009; and

·	the issuance of $80 million of 6.20% Series first mortgage bonds in April 2010; offset by

·	money pool activity.

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Entergy Mississippi, Inc.

Management’s Financial Discussion and Analysis

Increases in Entergy Mississippi’s payable to the money pool are a source of cash flow, and Entergy Mississippi’s payable to the money pool increased by $33.3 million in 2010 compared to decreasing by $66 million in 2009.

See Note 5 to the financial statements for details on long-term debt.

Capital Structure

Entergy Mississippi’s capitalization is balanced between equity and debt, as shown in the following table.

	December 31, 2011	December 31, 2010

Debt to capital	51.2%	51.9%
Effect of subtracting cash	0.0%	0.0%
Net debt to net capital	51.2%	51.9%

Net debt consists of debt less cash and cash equivalents. Debt consists of capital lease obligations and long-term debt, including the currently maturing portion. Capital consists of debt and equity. Net capital consists of capital less cash and cash equivalents. Entergy Mississippi uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Mississippi’s financial condition.

Uses of Capital

Entergy Mississippi requires capital resources for:

·	construction and other capital investments;

·	debt and preferred stock maturities or retirements;

·	working capital purposes, including the financing of fuel and purchased power costs; and

·	dividend and interest payments.

Following are the amounts of Entergy Mississippi’s planned construction and other capital investments, and existing debt obligations and lease obligations (includes estimated interest payments):

	2012	2013-2014	2015-2016	After 2016	Total
	(In Millions)
Planned construction and capital investment (1):
Generation	$233	$31	N/A	N/A	$264
Transmission	74	125	N/A	N/A	199
Distribution	72	159	N/A	N/A	231
Other	7	13	N/A	N/A	20
Total	$386	$328	N/A	N/A	$714
Long-term debt (2)	$51	$192	$214	$1,343	$1,800
Capital lease payments	$3	$5	$3	$2	$13
Operating leases	$6	$10	$5	$6	$27
Purchase obligations (3)	$221	$404	$400	$1,570	$2,595

(1)	Includes approximately $129 million annually for maintenance capital, which is planned spending on routine capital projects that are necessary to support reliability of service, equipment or systems, and to support normal customer growth.
(2)	Includes estimated interest payments. Long-term debt is discussed in Note 5 to the financial statements.
(3)	Purchase obligations represent the minimum purchase obligation or cancellation charge for contractual obligations to purchase goods or services. For Entergy Mississippi, almost all of the total consists of unconditional fuel and purchased power obligations, including its obligations under the Unit Power Sales Agreement, which is discussed in Note 8 to the financial statements.

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Entergy Mississippi, Inc.

Management’s Financial Discussion and Analysis

In addition to the contractual obligations given above, Entergy Mississippi currently expects to contribute approximately $8.4 million to its pension plans and approximately $5.5 million to other postretirement plans in 2012 although the required pension contributions will not be known with more certainty until the January 1, 2012 valuations are completed by April 1, 2012.

The planned capital investment estimate for Entergy Mississippi reflects capital required to support existing business and customer growth. Entergy’s Utility supply plan initiative will continue to seek to transform its generation portfolio with new or repowered generation resources. Opportunities resulting from the supply plan initiative, including new projects or the exploration of alternative financing sources, could result in increases or decreases in the capital expenditure estimates given above. The estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints, environmental compliance, market volatility, economic trends, changes in project plans, and the ability to access capital. Management provides more information on long-term debt and preferred stock maturities in Notes 5 and 6 to the financial statements.

As a wholly-owned subsidiary, Entergy Mississippi dividends its earnings to Entergy Corporation at a percentage determined monthly. Entergy Mississippi’s long-term debt indentures restrict the amount of retained earnings available for the payment of cash dividends or other distributions on its common and preferred stock. As of December 31, 2011, Entergy Mississippi had restricted retained earnings unavailable for distribution to Entergy Corporation of $68.5 million.

Hinds Energy Facility Purchase Agreement

New Nuclear Generation Development Costs

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Entergy Mississippi, Inc.

Management’s Financial Discussion and Analysis

generation resource development activities for new nuclear generation at Grand Gulf. The costs shall be treated as a regulatory asset until the proceeding is resolved. The Mississippi Public Utilities Staff and Entergy Mississippi also agree that the MPSC should conduct a hearing during 2012 to consider the relief requested by Entergy Mississippi in its application, including evidence regarding whether costs incurred in connection with planning, evaluation, monitoring, and other and related generation resource development activities for new nuclear generation at Grand Gulf were prudently incurred and are otherwise allowable. The Mississippi Public Utilities Staff and Entergy Mississippi further agree that such prudently incurred costs shall be recoverable in a manner to be determined by the MPSC. In the Stipulation, the Mississippi Public Utilities Staff and Entergy Mississippi agree that the development of a nuclear unit project option is consistent with the Mississippi Baseload Act. The Mississippi Public Utilities Staff and Entergy Mississippi further agree that the deferral of costs incurred in connection with planning, evaluation, monitoring, and other and related generation resource development activities for new nuclear generation at Grand Gulf also is consistent with the Mississippi Baseload Act. Entergy Mississippi will not accrue carrying charges or continue to accrue AFUDC on the costs, pending the outcome of the proceeding. The MPSC approved the stipulation in November 2011.

Sources of Capital

Entergy Mississippi’s sources to meet its capital requirements include:

·	internally generated funds;

·	cash on hand;

·	debt or preferred stock issuances; and

·	bank financing under new or existing facilities.

Entergy Mississippi may refinance, redeem, or otherwise retire debt and preferred stock prior to maturity, to the extent market conditions and interest and dividend rates are favorable.

All debt and common and preferred stock issuances by Entergy Mississippi require prior regulatory approval. Preferred stock and debt issuances are also subject to issuance tests set forth in its corporate charter, bond indenture, and other agreements. Entergy Mississippi has sufficient capacity under these tests to meet its foreseeable capital needs.

In May 2011, Entergy Mississippi renewed its three separate credit facilities through May 2012 in the aggregate amount of $70 million. No borrowings were outstanding under the credit facilities as of December 31, 2011.

Entergy Mississippi’s receivables from or (payables to) the money pool were as follows as of December 31 for each of the following years:

2011	2010	2009	2008
(In Thousands)

($1,999)	($33,255)	$31,435	($66,044)

Entergy Mississippi has obtained short-term borrowing authorization from the FERC under which it may borrow through October 2013, up to the aggregate amount, at any one time outstanding, of $175 million. See Note 4 to the financial statements for further discussion of Entergy Mississippi’s short-term borrowing limits. Entergy Mississippi has also obtained an order from the FERC authorizing long-term securities issuances through July 2013.

State and Local Rate Regulation and Fuel-Cost Recovery

The rates that Entergy Mississippi charges for electricity significantly influence its financial position, results of operations, and liquidity. Entergy Mississippi is regulated and the rates charged to its customers are determined in regulatory proceedings. A governmental agency, the MPSC, is primarily responsible for approval of the rates charged to customers.

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Entergy Mississippi, Inc.

Management’s Financial Discussion and Analysis

Formula Rate Plan

In March 2009, Entergy Mississippi made with the MPSC its annual scheduled formula rate plan filing for the 2008 test year. The filing reported a $27.0 million revenue deficiency and an earned return on common equity of 7.41%. Entergy Mississippi requested a $14.5 million increase in annual electric revenues, which is the maximum increase allowed under the terms of the formula rate plan. The MPSC issued an order on June 30, 2009, finding that Entergy Mississippi’s earned return was sufficiently below the lower bandwidth limit set by the formula rate plan to require a $14.5 million increase in annual revenues, effective for bills rendered on or after June 30, 2009.

Fuel and Purchased Power Cost Recovery

Mississippi Attorney General Complaint

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Entergy Mississippi, Inc.

Management’s Financial Discussion and Analysis

Federal Regulation

Critical Accounting Estimates

The preparation of Entergy Mississippi’s financial statements in conformity with generally accepted accounting principles requires management to apply appropriate accounting policies and to make estimates and judgments that can have a significant effect on reported financial position, results of operations, and cash flows. Management has identified the following accounting policies and estimates as critical because they are based on assumptions and measurements that involve a high degree of uncertainty, and there is the potential for future changes in the assumptions and measurements that could produce estimates that would have a material impact on the presentation of Entergy Mississippi’s financial position or results of operations.

Unbilled Revenue

As discussed in Note 1 to the financial statements, Entergy Mississippi records an estimate of the revenues earned for energy delivered since the latest customer billing. Each month the estimated unbilled revenue amounts are recorded as revenue and a receivable, and the prior month’s estimate is reversed. The difference between the estimate of the unbilled receivable at the beginning of the period and the end of the period is the amount of unbilled revenue recognized during the period. The estimate recorded is primarily based upon an estimate of customer usage during the unbilled period and the billed price to customers in that month. Therefore, revenue recognized may be affected by the estimated price and usage at the beginning and end of each period, in addition to changes in certain components of the calculation.

Qualified Pension and Other Postretirement Benefits

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Entergy Mississippi, Inc.

Management’s Financial Discussion and Analysis

Cost Sensitivity

The following chart reflects the sensitivity of qualified pension cost and qualified projected qualified benefit obligation to changes in certain actuarial assumptions (dollars in thousands):

Actuarial Assumption	Change in Assumption	Impact on 2011 Qualified Pension Cost	Impact on Projected Qualified Benefit Obligation
	Increase/(Decrease)

Discount rate	(0.25%)	$829	$10,541
Rate of return on plan assets	(0.25%)	$593	-
Rate of increase in compensation	0.25%	$346	$1,929

The following chart reflects the sensitivity of postretirement benefit cost and accumulated postretirement benefit obligation to changes in certain actuarial assumptions (dollars in thousands):

Actuarial Assumption	Change in Assumption	Impact on 2011 Postretirement Benefit Cost	Impact on Accumulated Postretirement Benefit Obligation
	Increase/(Decrease)

Health care cost trend	0.25%	$447	$2,776
Discount rate	(0.25%)	$318	$3,342

Each fluctuation above assumes that the other components of the calculation are held constant.

Costs and Funding

Total qualified pension cost for Entergy Mississippi in 2011 was $7.7 million. Entergy Mississippi anticipates 2012 qualified pension cost to be $12.3 million. Entergy Mississippi contributed $29.2 million to its qualified pension plans in 2011 and anticipates that it will contribute approximately $8.4 million in 2012 although the required pension contributions will not be known with more certainty until the January 1, 2012 valuations are completed by April 1, 2012.

Total postretirement health care and life insurance benefit costs for Entergy Mississippi in 2011 were $5.5 million, including $2 million in savings due to the estimated effect of future Medicare Part D subsidies. Entergy Mississippi expects 2012 postretirement health care and life insurance benefit costs to approximate $6.4 million, including $1.8 million in savings due to the estimated effect of future Medicare Part D subsidies. Entergy Mississippi expects to contribute approximately $5.5 million to its other postretirement plans in 2012.

Federal Healthcare Legislation

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Entergy Corporation and Subsidiaries Management’s Discussion and Analysis.

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of

Entergy Mississippi, Inc.

Jackson, Mississippi

We have audited the accompanying balance sheets of Entergy Mississippi, Inc. (the “Company”) as of December 31, 2011 and 2010, and the related income statements, statements of cash flows, and statements of changes in common equity (pages 338 through 342 and applicable items in pages 53 through 194) for each of the three years in the period ended December 31, 2011. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

In our opinion, such financial statements present fairly, in all material respects, the financial position of Entergy Mississippi, Inc. as of December 31, 2011 and 2010, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2011, in conformity with accounting principles generally accepted in the United States of America.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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ENTERGY MISSISSIPPI, INC.
INCOME STATEMENTS

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands)

OPERATING REVENUES
Electric	$	1,266,470		$	1,232,922		$	1,180,107

OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale		363,025			277,806			340,804
Purchased power		339,061			383,769			359,664
Other operation and maintenance		210,657			217,354			217,452
Taxes other than income taxes		69,759			66,841			63,381
Depreciation and amortization		93,119			89,875			86,872
Other regulatory charges (credits) - net		9,460			16,001			(57,056	)
TOTAL		1,085,081			1,051,646			1,011,117

OPERATING INCOME		181,389			181,276			168,990

OTHER INCOME
Allowance for equity funds used during construction		7,755			6,655			2,964
Interest and investment income		249			416			863
Miscellaneous - net		(3,904	)		(804	)		(564	)
TOTAL		4,100			6,267			3,263

INTEREST EXPENSE
Interest expense		52,273			55,774			51,282
Allowance for borrowed funds used during construction		(4,314	)		(3,719	)		(1,791	)
TOTAL		47,959			52,055			49,491

INCOME BEFORE INCOME TAXES		137,530			135,488			122,762

Income taxes		28,801			50,111			43,395

NET INCOME		108,729			85,377			79,367

Preferred dividend requirements and other		2,828			2,828			2,828

EARNINGS APPLICABLE TO
COMMON STOCK	$	105,901		$	82,549		$	76,539

See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, INC.
STATEMENTS OF CASH FLOWS

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands)

OPERATING ACTIVITIES
Net income	$	108,729		$	85,377		$	79,367
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization		93,119			89,875			86,872
Deferred income taxes, investment tax credits, and non-current taxes accrued		(3,443	)		48,744			15,923
Changes in assets and liabilities:
Receivables		5,488			(42,790	)		41,247
Fuel inventory		(35,621	)		(1,003	)		3,413
Accounts payable		(7,059	)		1,906			3,511
Taxes accrued		13,535			(12,817	)		1,779
Interest accrued		456			1,915			2,066
Deferred fuel costs		18,998			(76,064	)		77,932
Other working capital accounts		(27,480	)		46,101			(37,373	)
Provisions for estimated losses		(1,177	)		(1,937	)		4,446
Other regulatory assets		(83,399	)		(5,780	)		(43,807	)
Pension and other postretirement liabilities		39,183			(6,525	)		(6,786	)
Other assets and liabilities		(21,733	)		(6,895	)		(6,572	)
Net cash flow provided by operating activities		99,596			120,107			222,018

INVESTING ACTIVITIES
Construction expenditures		(165,998	)		(223,787	)		(130,907	)
Allowance for equity funds used during construction		7,755			6,655			2,964
Proceeds from sale of assets		868			3,951			-
Change in money pool receivable - net		-			31,435			(31,435	)
Changes in other investments - net		18			7,615			-
Payment to storm reserve escrow account		-			-			(175	)
Investments in affiliates		5,527			-			-
Other		-			35			80
Net cash flow used in investing activities		(151,830	)		(174,096	)		(159,473	)

FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		268,418			76,727			147,996
Retirement of long-term debt		(180,000	)		(100,000	)		-
Change in money pool payable - net		(31,256	)		33,255			(66,044	)
Dividends paid:
Common stock		(3,300	)		(43,400	)		(51,300	)
Preferred stock		(2,828	)		(2,828	)		(2,828	)
Net cash flow provided by (used in) financing activities		51,034			(36,246	)		27,824

Net increase (decrease) in cash and cash equivalents		(1,200	)		(90,235	)		90,369

Cash and cash equivalents at beginning of period		1,216			91,451			1,082

Cash and cash equivalents at end of period	$	16		$	1,216		$	91,451

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized	$	49,192		$	51,250		$	47,007
Income taxes	$	22,094		$	16,401		$	23,478

See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, INC.
BALANCE SHEETS
ASSETS

	December 31,
	2011			2010
	(In Thousands)

CURRENT ASSETS
Cash and cash equivalents:
Cash	$	7		$	1,207
Temporary cash investments		9			9
Total cash and cash equivalents		16			1,216
Accounts receivable:
Customer		51,026			58,204
Allowance for doubtful accounts		(756	)		(985	)
Associated companies		51,329			52,946
Other		13,924			7,500
Accrued unbilled revenues		38,368			41,714
Total accounts receivable		153,891			159,379
Deferred fuel costs		-			3,157
Accumulated deferred income taxes		11,694			19,308
Fuel inventory - at average cost		42,499			6,878
Materials and supplies - at average cost		35,716			34,499
Prepayments and other		4,666			4,902
TOTAL		248,482			229,339

OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)		4,725			4,753
Storm reserve escrow account		31,844			31,862
TOTAL		36,569			36,615

UTILITY PLANT
Electric		3,274,031			3,174,148
Property under capital lease		10,721			13,197
Construction work in progress		105,083			147,169
TOTAL UTILITY PLANT		3,389,835			3,334,514
Less - accumulated depreciation and amortization		1,210,092			1,166,463
UTILITY PLANT - NET		2,179,743			2,168,051

DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Regulatory asset for income taxes - net		65,196			63,533
Other regulatory assets		393,387			253,231
Other		20,017			22,009
TOTAL		478,600			338,773

TOTAL ASSETS	$	2,943,394		$	2,772,778

See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, INC.
BALANCE SHEETS
LIABILITIES AND EQUITY

	December 31,
	2011			2010
	(In Thousands)

CURRENT LIABILITIES
Currently maturing long-term debt	$	-		$	80,000
Accounts payable:
Associated companies		46,311			75,128
Other		41,489			53,417
Customer deposits		68,610			65,873
Taxes accrued		45,536			32,001
Interest accrued		21,550			21,094
Deferred fuel costs		15,841			-
System agreement cost equalization		-			36,650
Other		17,474			9,895
TOTAL		256,811			374,058

NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued		672,129			680,467
Accumulated deferred investment tax credits		6,372			6,541
Obligations under capital lease		8,112			10,747
Other regulatory liabilities		-			262
Asset retirement cost liabilities		5,697			5,375
Accumulated provisions		38,289			39,466
Pension and other postretirement liabilities		144,088			104,912
Long-term debt		920,439			745,378
Other		5,370			22,086
TOTAL		1,800,496			1,615,234

Commitments and Contingencies

Preferred stock without sinking fund		50,381			50,381

COMMON EQUITY
Common stock, no par value, authorized 12,000,000
shares; issued and outstanding 8,666,357 shares in 2011 and 2010		199,326			199,326
Capital stock expense and other		(690	)		(690	)
Retained earnings		637,070			534,469
TOTAL		835,706			733,105

TOTAL LIABILITIES AND EQUITY	$	2,943,394		$	2,772,778

See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, INC.
STATEMENTS OF CHANGES IN COMMON EQUITY
For the Years Ended December 31, 2011, 2010, and 2009

	Common Equity
	Common Stock		Capital Stock Expense and Other			Retained Earnings			Total
	(In Thousands)

Balance at December 31, 2008	$	199,326	$	(690	)	$	470,081		$	668,717
Net income		-		-			79,367			79,367
Common stock dividends		-		-			(51,300	)		(51,300	)
Preferred stock dividends		-		-			(2,828	)		(2,828	)
Balance at December 31, 2009	$	199,326	$	(690	)	$	495,320		$	693,956
Net income		-		-			85,377			85,377
Common stock dividends		-		-			(43,400	)		(43,400	)
Preferred stock dividends		-		-			(2,828	)		(2,828	)
Balance at December 31, 2010	$	199,326	$	(690	)	$	534,469		$	733,105
Net income		-		-			108,729			108,729
Common stock dividends		-		-			(3,300	)		(3,300	)
Preferred stock dividends		-		-			(2,828	)		(2,828	)
Balance at December 31, 2011	$	199,326	$	(690	)	$	637,070		$	835,706

See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, INC.
SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON

	2011		2010		2009		2008		2007
	(In Thousands)

Operating revenues	$	1,266,470	$	1,232,922	$	1,180,107	$	1,464,699	$	1,374,011
Net Income	$	108,729	$	85,377	$	79,367	$	61,264	$	72,853
Total assets	$	2,943,394	$	2,772,778	$	2,689,933	$	2,533,746	$	2,389,355
Long-term obligations (1)	$	978,932	$	806,506	$	900,634	$	752,129	$	753,453

(1) Includes long-term debt (excluding currently maturing debt), noncurrent capital lease obligations, and preferred stock without sinking fund.

		2011		2010		2009		2008		2007
	(Dollars In Millions)
Electric Operating Revenues:
Residential	$	490	$	509	$	467	$	556	$	500
Commercial		401		406		395		482		428
Industrial		146		145		147		199		185
Governmental		37		38		37		44		40
Total retail		1,074		1,098		1,046		1,281		1,153
Sales for resale:
Associated companies		104		55		52		96		140
Non-associated companies		27		33		28		36		33
Other		61		47		54		52		48
Total	$	1,266	$	1,233	$	1,180	$	1,465	$	1,374
Billed Electric Energy Sales (GWh):
Residential		5,848		6,077		5,358		5,354		5,474
Commercial		4,985		5,000		4,756		4,841		4,872
Industrial		2,326		2,250		2,178		2,565		2,771
Governmental		415		416		405		411		421
Total retail		13,574		13,743		12,697		13,171		13,538
Sales for resale:
Associated companies		431		268		198		534		1,025
Non-associated companies		332		402		330		401		468
Total		14,337		14,413		13,225		14,106		15,031

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ENTERGY NEW ORLEANS, INC.

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Plan to Spin Off the Utility’s Transmission Business

Results of Operations

Net Income

2011 Compared to 2010

Net income increased $4.9 million primarily due to lower other operation and maintenance expenses, lower taxes other than income taxes, a lower effective income tax rate, and lower interest expense, partially offset by lower net revenue.

2010 Compared to 2009

Net income remained relatively unchanged, increasing $0.6 million, primarily due to higher net revenue and lower interest expense, almost entirely offset by higher other operation and maintenance expenses, higher taxes other than income taxes, lower other income, and higher depreciation and amortization expenses.

Net Revenue

2011 Compared to 2010

		Amount
		(In Millions)

2010 net revenue		$272.9
Retail electric price		(16.9)
Net gas revenue		(9.1)
Gas cost recovery asset		(3.0)
Volume/weather		5.4
Other		(2.3)
2011 net revenue		$247.0

The retail electric price variance is primarily due to formula rate plan decreases effective October 2010 and October 2011. See Note 2 to the financial statements for a discussion of the formula rate plan filing.

The net gas revenue variance is primarily due to milder weather in 2011 compared to 2010.

The gas cost recovery asset variance is primarily due to the recognition in 2010 of a $3 million gas operations regulatory asset associated with the settlement of Entergy New Orleans’s electric and gas formula rate plan case and the amortization of that asset. See Note 2 to the financial statements for additional discussion of the formula rate plan settlement.

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Entergy New Orleans, Inc.

Management’s Financial Discussion and Analysis

The volume/weather variance is primarily due to an increase in electricity usage in the residential and commercial sectors due in part to a 4% increase in the average number of residential customers and a 3% increase in the average number of commercial customers, partially offset by the effect of less favorable weather on residential sales.

Gross operating revenues

Gross operating revenues decreased primarily due to:

·	a decrease of $16.2 million in electric fuel cost recovery revenues due to lower fuel rates;

·	a decrease of $15.4 million in gross gas revenues primarily due to lower fuel cost recovery revenues as a result of lower fuel rates and the effect of milder weather; and

·	formula rate plan decreases effective October 2010 and October 2011, as discussed above.

The decrease was partially offset by an increase in gross wholesale revenue due to increased sales to affiliated customers and more favorable volume/weather, as discussed above.

2010 Compared to 2009

		Amount
		(In Millions)

2009 net revenue		$243.0
Volume/weather		17.0
Net gas revenue		14.2
Effect of 2009 rate case settlement		(6.6)
Other		5.3
2010 net revenue		$272.9

The volume/weather variance is primarily due to an increase of 348 GWh, or 7%, in billed retail electricity usage primarily due to more favorable weather compared to last year.

The net gas revenue variance is primarily due to more favorable weather compared to last year, along with the recognition of a gas regulatory asset associated with the settlement of Entergy New Orleans’s electric and gas formula rate plans. See Note 2 to the financial statements for further discussion of the formula rate plan settlement.

The effect of 2009 rate case settlement variance results from the April 2009 settlement of Entergy New Orleans’s rate case, and includes the effects of realigning non-fuel costs associated with the operation of Grand Gulf from the fuel adjustment clause to electric base rates effective June 2009. See Note 2 to the financial statements for further discussion of the rate case settlement.

Other Income Statement Variances

2011 Compared to 2010

Other operation and maintenance expenses decreased primarily due to the deferral in 2011 of $13.4 million of 2010 Michoud plant maintenance costs pursuant to the settlement of Entergy New Orleans’s 2010 test year formula rate plan filing approved by the City Council in September 2011 and a decrease of $8.0 million in fossil-fueled generation expenses due to higher plant outage costs in 2010 due to a greater scope of work at the Michoud plant. See Note 2 to the financial statements for more discussion of the 2010 test year formula rate plan filing.

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Taxes other than income taxes decreased primarily due to a decrease in local franchise taxes resulting from lower electric and gas retail revenues as compared with the same period in 2010.

Interest expense decreased primarily due to the repayment in May 2010 of the notes payable issued to affiliates as part of Entergy New Orleans’s plan of reorganization and the repayment, at maturity, of $30 million of 4.98% Series first mortgage bonds in July 2010.

2010 Compared to 2009

Other operation and maintenance expenses increased primarily due to:

·	an increase of $15.1 million in fossil expenses due to higher outage expenses compared to prior year;

·	an increase of $2.2 million in distribution expenses primarily due to increases in vegetation maintenance, overhead and underground inspections, and substation maintenance and repairs; and

an increase of $1.9 million in compensation and benefits costs, resulting from decreasing discount rates, the amortization of benefit trust asset losses, and an increase in the accrual for incentive-based compensation. See Note 11 to the financial statements for further discussion of benefits costs.

Taxes other than income taxes increased primarily due to an increase in ad valorem taxes as a result of higher millage rates and an increase in local franchise taxes resulting from higher electric and gas retail revenues as compared with the same period in 2009.

Depreciation and amortization expenses increased primarily due to an increase in plant in service.

Other income decreased primarily due to carrying costs on Hurricane Gustav and Hurricane Ike storm restoration costs recorded in 2009.

Interest expense decreased primarily due to a decrease in the interest rate on notes payable issued to affiliates as part of Entergy New Orleans’s plan of reorganization, in addition to the repayment of those notes in May 2010 and the repayment, at maturity, of $30 million of 4.98% Series first mortgage bonds in July 2010.

Income Taxes

The effective income tax rates for 2011, 2010, and 2009 were 30.6%, 34.8%, and 33.5%, respectively. See Note 3 to the financial statements for a reconciliation of the federal statutory rate of 35% to the effective income tax rates.

Hurricane Katrina

In August 2005, Hurricane Katrina caused catastrophic damage to Entergy New Orleans’s service territory. Entergy pursued a broad range of initiatives to recover storm restoration and business continuity costs, including obtaining assistance through federal legislation for damage caused by Hurricane Katrina.

Community Development Block Grant (CDBG)

In December 2005, the U.S. Congress passed the Katrina Relief Bill, a hurricane aid package that included CDBG funding that allowed state and local leaders to fund individual recovery priorities. In March 2007, the City Council certified that Entergy New Orleans incurred $205 million in storm-related costs through December 2006 that are eligible for CDBG funding under the state action plan, and certified Entergy New Orleans’s estimated costs of $465 million for its gas system rebuild (which is discussed below). Entergy New Orleans received $180.8 million of CDBG funds in 2007 and $19.2 million in 2010.

Gas System Rebuild

In addition to the Hurricane Katrina storm restoration costs that Entergy New Orleans incurred, Entergy New Orleans expects that over a longer term rebuilding of the gas system in New Orleans will be necessary due to the massive salt water intrusion into the system caused by the flooding in New Orleans. The salt water intrusion is expected to shorten the life of the gas system, making it necessary to rebuild portions of that system over time, earlier

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than otherwise would be expected, with the project extending many years into the future. Entergy New Orleans received insurance proceeds for a portion of the estimated future construction expenditures associated with rebuilding its gas system, and the October 2006 City Council resolution approving the settlement of Entergy New Orleans’s rate and storm-cost recovery filings requires Entergy New Orleans to record those proceeds in a designated sub-account of other deferred credits until the proceeds are spent on the rebuild project. This other deferred credit is shown as “Gas system rebuild insurance proceeds” on Entergy New Orleans’s balance sheet.

Bankruptcy Proceedings

As a result of the effects of Hurricane Katrina and the effect of extensive flooding that resulted from levee breaks in and around the New Orleans area, on September 23, 2005, Entergy New Orleans filed a voluntary petition in bankruptcy court seeking reorganization relief under Chapter 11 of the U.S. Bankruptcy Code. On May 7, 2007, the bankruptcy judge entered an order confirming Entergy New Orleans’s plan of reorganization. With the receipt of CDBG funds, and the agreement on insurance recovery with one of its excess insurers, Entergy New Orleans waived the conditions precedent in its plan of reorganization, and the plan became effective on May 8, 2007. Included in the terms in the plan of reorganization Entergy New Orleans issued notes to affiliates. Entergy New Orleans repaid, at maturity in May 2010, these notes that represented affiliate prepetition accounts payable (approximately $74 million, including interest), including its indebtedness to the Entergy System money pool.

Liquidity and Capital Resources

Cash Flow

Cash flows for the years ended December 31, 2011, 2010, and 2009 were as follows:

		2011	2010	2009
		(In Thousands)

Cash and cash equivalents at beginning of period		$54,986	$191,191	$137,444

Cash flow provided by (used in):
	Operating activities	44,927	48,965	148,556
	Investing activities	(46,019)	(31,561)	(59,848)
	Financing activities	(44,060)	(153,609)	(34,961)
	Net increase (decrease) in cash and cash equivalents	(45,152)	(136,205)	53,747

Cash and cash equivalents at end of period		$9,834	$54,986	$191,191

Operating Activities

Net cash flow provided by operating activities was relatively flat in 2011 as the receipt of $19.2 million of Community Development Block Grant funds in 2010 related to Hurricane Katrina costs was offset by a decrease of $28.8 million in income tax payments in 2011. The decrease in income tax payments is in accordance with the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement. The decrease results from lower 2010 taxable income from what was estimated due to revised bonus depreciation deduction and additional repair expenses for tax purposes associated with the tax accounting method change filed in 2010.

Net cash flow provided by operating activities decreased $99.6 million in 2010 primarily due to income tax payments of $68.2 million made in 2010 compared to refunds of $22.1 million received in 2009 and an increase in pension contributions of $11.9 million. In 2010, Entergy New Orleans made tax payments in accordance with the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement. The payments resulted from the reversal of temporary differences for which Entergy New Orleans previously received cash tax benefits and from estimated federal income tax payments for tax year 2010. See “MANAGEMENT’S

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FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates” below for a discussion of qualified pension and other postretirement benefits. The decrease was partially offset by the receipt of $19.2 million of Community Development Block Grant funds, as discussed above.

Investing Activities

Net cash flow used in investing activities increased $14.5 million in 2011 primarily due to money pool activity and a withdrawal in 2010 from the storm escrow account related to Hurricane Gustav costs. The increase was partially offset by a decrease in construction expenditures due to decreased spending on the gas system rebuild project and System Fuels repayment of Entergy New Orleans’s $3.3 million investment in System Fuels.

Decreases in Entergy New Orleans’s receivable from the money pool are a source of cash flow, and Entergy New Orleans’s receivable from the money pool decreased $12.7 million in 2011 compared to decreasing $44.3 million in 2010. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Net cash flow used in investing activities decreased $28.3 million in 2010 primarily due to money pool activity and a withdrawal from the storm escrow account that was related to Hurricane Gustav costs, partially offset by:

·	higher fossil construction expenses primarily due to current year outages and the Michoud 3 generator rewind project;

·	higher distribution construction expenditures primarily due to increased reliability work; and

·	a decrease in Hurricane Katrina insurance proceeds received in 2010 as compared to 2009.

Decreases in Entergy New Orleans’s receivable from the money pool are a source of cash flow, and Entergy New Orleans’s receivable from the money pool decreased $44.3 million in 2010 compared to increasing $6.1 million in 2009.

Financing Activities

Net cash flow used in financing activities decreased $109.5 million in 2011 primarily due to the repayment in 2010 of $74.3 million of affiliate notes payable that were issued to affiliates as part of Entergy New Orleans’s plan of reorganization, the repayment, at maturity, of $30 million of 4.98% Series first mortgage bonds in July 2010, and the repayment of $25 million of 6.75% Series first mortgage bonds in December 2010, offset by the issuance of $25 million of 5.10% Series first mortgage bonds in November 2010.

Net cash flow used in financing activities increased $118.6 million in 2010 primarily due to:

·	the repayment of $74.3 million of affiliate notes payable in May 2010;

·	the repayment, at maturity, of $30 million of 4.98% Series first mortgage bonds in July 2010;

·	the repayment of $25 million of 6.75% Series first mortgage bonds in December 2010; and

·	an increase of $14.1 million in dividends paid on common stock.

The increase was partially offset by the issuance of $25 million of 5.10% Series first mortgage bonds in November 2010.

See Note 5 to the financial statements for details on long-term debt.

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Management’s Financial Discussion and Analysis

Capital Structure

Entergy New Orleans’s capitalization is balanced between equity and debt as shown in the following table.

	December 31, 2011	December 31, 2010

Debt to capital	45.3%	44.6%
Effect of subtracting cash	(1.5)%	(9.5)%
Net debt to net capital	43.8%	35.1%

Net debt consists of debt less cash and cash equivalents. Debt consists of notes payable and long-term debt, including the currently maturing portion. Capital consists of debt and equity. Net capital consists of capital less cash and cash equivalents. Entergy New Orleans uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy New Orleans’s financial condition.

Uses of Capital

Entergy New Orleans requires capital resources for:

·	construction and other capital investments;

·	working capital purposes, including the financing of fuel and purchased power costs;

·	debt and preferred stock maturities or retirements; and

·	dividend payments.

Following are the amounts of Entergy New Orleans’s planned construction and other capital investments and existing debt and lease obligations (includes estimated interest payments):

	2012	2013-2014	2015-2016	After 2016	Total
	(In Millions)
Planned construction and capital investment (1):
Generation	$8	$33	N/A	N/A	$41
Transmission	7	10	N/A	N/A	17
Distribution	28	52	N/A	N/A	80
Other	21	45	N/A	N/A	66
Total	$64	$140	N/A	N/A	$204
Long-term debt (2)	$9	$83	$11	$143	$246
Operating leases	$2	$3	$2	$-	$7
Purchase obligations (3)	$179	$329	$319	$1,627	$2,454

(1)	Includes approximately $43 million annually for maintenance capital, which is planned spending on routine capital projects that are necessary to support reliability of service, equipment or systems and to support normal customer growth. Also includes spending for the long-term gas rebuild project.
(2)	Includes estimated interest payments. Long-term debt is discussed in Note 5 to the financial statements.
(3)	Purchase obligations represent the minimum purchase obligation or cancellation charge for contractual obligations to purchase goods or services. For Entergy New Orleans, almost all of the total consists of unconditional fuel and purchased power obligations, including its obligations under the Unit Power Sales Agreement, which is discussed in Note 8 to the financial statements.

Entergy New Orleans expects to contribute approximately $4.8 million to its pension plan and approximately $3.7 million to its other postretirement plans in 2012 although the required pension contributions will not be known with more certainty until the January 1, 2012 valuations are completed by April 1, 2012.

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Management’s Financial Discussion and Analysis

Also in addition to the contractual obligations, Entergy New Orleans has $53.7 million of unrecognized tax benefits and interest net of unused tax attributes and payments for which the timing of payments beyond 12 months cannot be reasonably estimated due to uncertainties in the timing of effective settlement of tax positions. See Note 3 to the financial statements for additional information regarding unrecognized tax benefits.

The planned capital investment estimate for Entergy New Orleans reflects capital required to support existing business. The estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints, environmental compliance, market volatility, economic trends, changes in project plans, and the ability to access capital. Management provides more information on long-term debt and preferred stock maturities in Notes 5 and 6 and to the financial statements.

As an indirect, wholly-owned subsidiary of Entergy Corporation, Entergy New Orleans pays dividends from its earnings at a percentage determined monthly. Entergy New Orleans’s long-term debt indentures contain restrictions on the payment of cash dividends or other distributions on its common and preferred stock.

Sources of Capital

Entergy New Orleans’s sources to meet its capital requirements include:

·	internally generated funds;

·	cash on hand; and

·	debt and preferred stock issuances.

Entergy New Orleans may refinance, redeem, or otherwise retire debt and preferred stock prior to maturity, to the extent market conditions and interest and dividend rates are favorable.

Entergy New Orleans’s receivables from the money pool were as follows as of December 31 for each of the following years:

2011	2010	2009	2008
(In Thousands)

$9,074	$21,820	$66,149	$60,093

See Note 4 to the financial statements for a description of the money pool.

Entergy New Orleans has obtained short-term borrowing authorization from the FERC under which it may borrow through October 2013, up to the aggregate amount, at any one time outstanding, of $100 million. See Note 4 to the financial statements for further discussion of Entergy New Orleans’s short-term borrowing limits. The long-term securities issuances of Entergy New Orleans are limited to amounts authorized by the City Council, and the current authorization extends through July 2012.

Entergy Louisiana’s Ninemile Point Unit 6 Self-Build Project

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State and Local Rate Regulation

The rates that Entergy New Orleans charges for electricity and natural gas significantly influence its financial position, results of operations, and liquidity. Entergy New Orleans is regulated and the rates charged to its customers are determined in regulatory proceedings. A governmental agency, the City Council, is primarily responsible for approval of the rates charged to customers.

Rate Cases, Formula Rate Plans and Storm-related Riders

On July 31, 2008, Entergy New Orleans filed an electric and gas base rate case with the City Council. On April 2, 2009, the City Council approved a comprehensive settlement. The settlement provided for a net $35.3 million reduction in combined fuel and non-fuel electric revenue requirement, including conversion of a $10.6 million voluntary recovery credit, implemented in January 2008, to a permanent reduction and substantial realignment of Grand Gulf cost recovery from fuel to electric base rates, and a $4.95 million gas base rate increase, both effective June 1, 2009, with adjustment of the customer charges for all rate classes. A new three-year formula rate plan was also adopted, with terms including an 11.1% benchmark electric return on common equity (ROE) with a +/- 40 basis point bandwidth and a 10.75% benchmark gas ROE with a +/- 50 basis point bandwidth. Earnings outside the bandwidth reset to the midpoint benchmark ROE, with rates changing on a prospective basis depending on whether Entergy New Orleans is over- or under-earning. The formula rate plan also includes a recovery mechanism for City Council-approved capacity additions, plus provisions for extraordinary cost changes and force majeure events.

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Federal Regulation

Environmental Risks

Entergy New Orleans’s facilities and operations are subject to regulation by various governmental authorities having jurisdiction over air quality, water quality, control of toxic substances and hazardous solid wastes, and other environmental matters. Management believes that Entergy New Orleans is in substantial compliance with environmental regulations currently applicable to its facilities and operations. Because environmental regulations are subject to change, future compliance costs cannot be precisely estimated.

Critical Accounting Estimates

The preparation of Entergy New Orleans’s financial statements in conformity with generally accepted accounting principles requires management to apply appropriate accounting policies and to make estimates and judgments that can have a significant effect on reported financial position, results of operations, and cash flows. Management has identified the following accounting policies and estimates as critical because they are based on assumptions and measurements that involve a high degree of uncertainty, and there is the potential for future changes in the assumptions and measurements that could produce estimates that would have a material impact on the presentation of Entergy New Orleans’s financial position or results of operations.

Unbilled Revenue

As discussed in Note 1 to the financial statements, Entergy New Orleans records an estimate of the revenues earned for energy delivered since the latest customer billing. Each month the estimated unbilled revenue amounts are recorded as revenue and a receivable, and the prior month’s estimate is reversed. The difference between the estimate of the unbilled receivable at the beginning of the period and the end of the period is the amount of unbilled revenue recognized during the period. The estimate recorded is primarily based upon an estimate of customer usage during the unbilled period and the billed price to customers in that month, including fuel price. Therefore, revenue recognized may be affected by the estimated price and usage at the beginning and end of each period and fuel price fluctuations, in addition to changes in certain components of the calculation. Effective June 2009, Entergy New Orleans reclassified the fuel component of unbilled accounts receivable to deferred fuel and will no longer include the fuel component in the unbilled calculation, which is in accordance with regulatory treatment.

Qualified Pension and Other Postretirement Benefits

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Cost Sensitivity

The following chart reflects the sensitivity of qualified pension cost and qualified projected benefit obligation to changes in certain actuarial assumptions (dollars in thousands):

Actuarial Assumption	Change in Assumption	Impact on 2011 Qualified Pension Cost	Impact on Projected Qualified Benefit Obligation
	Increase/(Decrease)

Discount rate	(0.25%)	$408	$5,283
Rate of return on plan assets	(0.25%)	$249	-
Rate of increase in compensation	0.25%	$170	$1,027

The following chart reflects the sensitivity of postretirement benefit cost and accumulated postretirement benefit obligation to changes in certain actuarial assumptions (dollars in thousands):

Actuarial Assumption	Change in Assumption	Impact on 2011 Postretirement Benefit Cost	Impact on Accumulated Postretirement Benefit Obligation
	Increase/(Decrease)

Health care cost trend	0.25%	$269	$1,675
Discount rate	(0.25%)	$163	$2,057

Each fluctuation above assumes that the other components of the calculation are held constant.

Costs and Funding

Total qualified pension cost for Entergy New Orleans in 2011 was $5.5 million. Entergy New Orleans anticipates 2012 qualified pension cost to be $8.5 million. Entergy New Orleans contributed $12.2 million in qualified pension contributions in 2011 and anticipates approximately a $4.8 million pension contribution in 2012 although the required pension contributions will not be known with more certainty until the January 1, 2012 valuations are completed by April 1, 2012.

Total postretirement health care and life insurance benefit costs for Entergy New Orleans in 2011 were $3.7 million, including $1.2 million in savings due to the estimated effect of future Medicare Part D subsidies. Entergy New Orleans expects 2012 postretirement health care and life insurance benefit costs to approximate $4.2 million, including $1 million in savings due to the estimated effect of future Medicare Part D subsidies. Entergy New Orleans expects to contribute approximately $3.7 million to its other postretirement plans in 2012.

Federal Healthcare Legislation

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Entergy Corporation and Subsidiaries Management’s Discussion and Analysis.

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of

Entergy New Orleans, Inc.

New Orleans, Louisiana

We have audited the accompanying balance sheets of Entergy New Orleans, Inc. (the “Company”) as of December 31, 2011 and 2010, and the related income statements, statements of cash flows, and statements of changes in common equity (pages 356 through 360 and applicable items in pages 53 through 194) for each of the three years in the period ended December 31, 2011. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

In our opinion, such financial statements present fairly, in all material respects, the financial position of Entergy New Orleans, Inc. as of December 31, 2011 and 2010, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2011, in conformity with accounting principles generally accepted in the United States of America.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 27, 2012 expressed an unqualified opinion on the Company’s internal control over financial reporting.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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ENTERGY NEW ORLEANS, INC.
INCOME STATEMENTS

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands)

OPERATING REVENUES
Electric	$	529,228		$	543,102		$	535,985
Natural gas		100,957			116,347			104,437
TOTAL		630,185			659,449			640,422

OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale		173,668			169,644			196,917
Purchased power		207,604			218,025			198,836
Other operation and maintenance		106,817			130,917			108,716
Taxes other than income taxes		42,032			44,749			40,476
Depreciation and amortization		35,026			35,354			33,943
Other regulatory charges (credits) - net		1,910			(1,072	)		1,709
TOTAL		567,057			597,617			580,597

OPERATING INCOME		63,128			61,832			59,825

OTHER INCOME
Allowance for equity funds used during construction		622			667			230
Interest and investment income		154			544			3,762
Miscellaneous - net		(1,234	)		(2,478	)		(1,125	)
TOTAL		(458	)		(1,267	)		2,867

INTEREST EXPENSE
Interest expense		11,114			13,170			16,965
Allowance for borrowed funds used during construction		(282	)		(320	)		(98	)
TOTAL		10,832			12,850			16,867

INCOME BEFORE INCOME TAXES		51,838			47,715			45,825

Income taxes		15,862			16,601			15,346

NET INCOME		35,976			31,114			30,479

Preferred dividend requirements and other		965			965			965

EARNINGS APPLICABLE TO
COMMON STOCK	$	35,011		$	30,149		$	29,514

See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, INC.
STATEMENTS OF CASH FLOWS

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands)
OPERATING ACTIVITIES
Net income	$	35,976		$	31,114		$	30,479
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization		35,026			35,354			33,943
Deferred income taxes, investment tax credits, and non-current taxes accrued		(35,276	)		(47,611	)		54,797
Changes in assets and liabilities:
Receivables		24,275			(6,289	)		20,361
Fuel inventory		(1,160	)		(113	)		5,665
Accounts payable		(3,502	)		3,307			(3,224	)
Taxes accrued		-			-			(18,306	)
Interest accrued		12			(1,121	)		19
Deferred fuel costs		4,694			10,923			13,751
Other working capital accounts		(7,764	)		4,174			3,401
Provisions for estimated losses		4,637			(4,785	)		5,382
Other regulatory assets		(42,667	)		(10,073	)		(2,227	)
Pension and other postretirement liabilities		25,202			5,042			(5,549	)
Other assets and liabilities		5,474			29,043			10,064
Net cash flow provided by operating activities		44,927			48,965			148,556

INVESTING ACTIVITIES
Construction expenditures		(56,600	)		(80,218	)		(61,954	)
Allowance for equity funds used during construction		622			667			230
Insurance proceeds		-			115			14,553
Investments in affiliates		3,256			-			-
Change in money pool receivable - net		12,746			44,329			(6,056	)
Changes in other investments - net		(6,043	)		3,546			(6,621	)
Net cash flow used in investing activities		(46,019	)		(31,561	)		(59,848	)

FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		-			24,349			-
Retirement of long-term debt		-			(129,993	)		(728	)
Dividends paid:
Common stock		(42,000	)		(47,000	)		(32,900	)
Preferred stock		(965	)		(965	)		(965	)
Other		(1,095	)		-			(368	)
Net cash flow used in financing activities		(44,060	)		(153,609	)		(34,961	)

Net increase (decrease) in cash and cash equivalents		(45,152	)		(136,205	)		53,747

Cash and cash equivalents at beginning of period		54,986			191,191			137,444

Cash and cash equivalents at end of period	$	9,834		$	54,986		$	191,191

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid/(received) during the period for:
Interest - net of amount capitalized	$	10,109		$	13,550		$	16,302
Income taxes	$	39,403		$	68,160		$	(22,054	)

See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, INC.
BALANCE SHEETS
ASSETS

	December 31,
	2011			2010
	(In Thousands)

CURRENT ASSETS
Cash and cash equivalents
Cash	$	486		$	1,386
Temporary cash investments		9,348			53,600
Total cash and cash equivalents		9,834			54,986
Accounts receivable:
Customer		29,038			38,160
Allowance for doubtful accounts		(465	)		(734	)
Associated companies		12,167			39,037
Other		2,603			1,824
Accrued unbilled revenues		17,023			19,100
Total accounts receivable		60,366			97,387
Accumulated deferred income taxes		6,419			15,092
Fuel inventory - at average cost		3,806			2,646
Materials and supplies - at average cost		9,392			9,896
Prepayments and other		2,679			7,708
TOTAL		92,496			187,715

OTHER PROPERTY AND INVESTMENTS
Non-utility property at cost (less accumulated depreciation)		1,016			1,016
Storm reserve escrow account		11,996			5,953
TOTAL		13,012			6,969

UTILITY PLANT
Electric		812,329			822,003
Natural gas		213,160			206,148
Construction work in progress		13,610			11,669
TOTAL UTILITY PLANT		1,039,099			1,039,820
Less - accumulated depreciation and amortization		525,621			531,871
UTILITY PLANT - NET		513,478			507,949

DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Deferred fuel costs		4,080			4,080
Other regulatory assets		178,815			135,282
Other		4,154			8,081
TOTAL		187,049			147,443

TOTAL ASSETS	$	806,035		$	850,076

See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, INC.
BALANCE SHEETS
LIABILITIES AND EQUITY

	December 31,
	2011		2010
	(In Thousands)

CURRENT LIABILITIES
Accounts payable:
Associated companies	$	27,042	$	25,140
Other		28,098		30,093
Customer deposits		21,878		21,206
Interest accrued		2,840		2,828
Deferred fuel costs		11,621		6,927
System agreement cost equalization		-		15,510
Other		4,197		2,655
TOTAL CURRENT LIABILITIES		95,676		104,359

NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued		144,405		180,290
Accumulated deferred investment tax credits		1,539		1,835
Regulatory liability for income taxes - net		33,258		40,142
Other regulatory liabilities		5,726		22
Asset retirement cost liabilities		2,893		3,396
Accumulated provisions		15,843		11,206
Pension and other postretirement liabilities		74,017		48,815
Long-term debt		166,537		167,215
Gas system rebuild insurance proceeds		55,707		75,700
Other		9,489		9,162
TOTAL NON-CURRENT LIABILITIES		509,414		537,783


Commitments and Contingencies

Preferred stock without sinking fund		19,780		19,780

COMMON EQUITY
Common stock, $4 par value, authorized 10,000,000
shares; issued and outstanding 8,435,900 shares in 2011
and 2010		33,744		33,744
Paid-in capital		36,294		36,294
Retained earnings		111,127		118,116
TOTAL		181,165		188,154

TOTAL LIABILITIES AND EQUITY	$	806,035	$	850,076

See Notes to Financial Statements.

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STATEMENTS OF CHANGES IN COMMON EQUITY
For the Years Ended December 31, 2011, 2010, and 2009

	Common Equity
	Common Stock		Paid-in Capital		Retained Earnings			Total
	(In Thousands)

Balance at December 31, 2008	$	33,744	$	36,294	$	138,353		$	208,391
Net income		-		-		30,479			30,479
Common stock dividends		-		-		(32,900	)		(32,900	)
Preferred stock dividends		-		-		(965	)		(965	)
Balance at December 31, 2009	$	33,744	$	36,294	$	134,967		$	205,005
Net income		-		-		31,114			31,114
Common stock dividends		-		-		(47,000	)		(47,000	)
Preferred stock dividends		-		-		(965	)		(965	)
Balance at December 31, 2010	$	33,744	$	36,294	$	118,116		$	188,154
Net income		-		-		35,976			35,976
Common stock dividends		-		-		(42,000	)		(42,000	)
Preferred stock dividends		-		-		(965	)		(965	)
Balance at December 31, 2011	$	33,744	$	36,294	$	111,127		$	181,165

See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, INC.
SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON

	2011		2010		2009		2008		2007
	(In Thousands)

Operating revenues	$	630,185	$	659,449	$	640,422	$	814,383	$	676,927
Net Income	$	35,976	$	31,114	$	30,479	$	34,337	$	24,091
Total assets	$	806,035	$	850,076	$	995,818	$	998,460	$	872,141
Long-term obligations (1)	$	186,317	$	186,995	$	187,803	$	292,753	$	293,692

(1) Includes long-term debt (excluding currently maturing debt) and preferred stock without sinking fund.

		2011		2010		2009		2008		2007
	(Dollars In Millions)
Electric Operating Revenues:
Residential	$	176	$	196	$	168	$	172	$	142
Commercial		154		174		166		194		181
Industrial		30		36		37		48		47
Governmental		59		70		70		79		72
Total retail		419		476		441		493		442
Sales for resale:
Associated companies		95		56		87		161		103
Non-associated companies		1		1		1		2		1
Other		14		10		7		17		11
Total	$	529	$	543	$	536	$	673	$	557
Billed Electric Energy Sales (GWh):
Residential		1,888		1,858		1,577		1,394		1,221
Commercial		1,939		1,899		1,813		1,774		1,763
Industrial		498		503		526		541		568
Governmental		795		809		805		774		747
Total retail		5,120		5,069		4,721		4,483		4,299
Sales for resale:
Associated companies		1,167		906		1,528		1,336		995
Non-associated companies		19		13		15		25		15
Total		6,306		5,988		6,264		5,844		5,309

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ENTERGY TEXAS, INC. AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Plan to Spin Off the Utility’s Transmission Business

Results of Operations

Net Income

2011 Compared to 2010

Net income increased by $14.6 million primarily due to higher net revenue, partially offset by higher taxes other than income taxes, higher other operation and maintenance expenses, and higher depreciation and amortization expenses.

2010 Compared to 2009

Net income increased by $2.4 million primarily due to higher net revenue and lower interest expense, partially offset by lower other income, higher taxes other than income taxes, and higher other operation and maintenance expenses.

Net Revenue

2011 Compared to 2010

		Amount
		(In Millions)

2010 net revenue		$540.2
Retail electric price		36.0
Volume/weather		21.3
Purchased power capacity		(24.6)
Other		4.9
2011 net revenue		$577.8

The retail electric price variance is primarily due to rate actions, including an annual base rate increase of $59 million beginning August 2010, with an additional increase of $9 million beginning May 2011, as a result of the settlement of the December 2009 rate case. See Note 2 to the financial statements for further discussion of the rate case settlement.

The volume/weather variance is primarily due to an increase of 721 GWh, or 4.5%, in billed electricity usage, including the effect of more favorable weather on residential and commercial sales compared to last year. Usage in the industrial sector increased 8.2% primarily in the chemicals and refining industries.

The purchased power capacity variance is primarily due to price increases for ongoing purchased power capacity and additional capacity purchases.

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Gross operating revenues, fuel and purchased power expenses, and other regulatory charges

Gross operating revenues increased primarily due to the base rate increases and the volume/weather effect, as discussed above.

Fuel and purchased power expenses increased primarily due to an increase in demand coupled with an increase in deferred fuel expense as a result of lower fuel refunds in 2011 versus 2010, partially offset by a decrease in the average market price of natural gas.

Other regulatory charges decreased primarily due to the distribution in the first quarter 2011 of $17.4 million to customers of the 2007 rough production cost equalization remedy receipts. See Note 2 to the financial statements for further discussion of the rough production cost equalization proceedings.

2010 Compared to 2009

		Amount
		(In Millions)

2009 net revenue		$485.1
Net wholesale revenue		27.7
Volume/weather		27.2
Rough production cost equalization		18.6
Retail electric price		16.3
Securitization transition charge		15.3
Purchased power capacity		(44.3)
Other		(5.7)
2010 net revenue		$540.2

The net wholesale revenue variance is primarily due to increased sales to municipal and co-op customers due to the addition of new contracts.

The volume/weather variance is primarily due to increased electricity usage primarily in the residential and commercial sectors, resulting from a 1.5% increase in customers, coupled with the effect of more favorable weather on residential sales. Billed electricity usage increased a total of 777 GWh, or 5%.

The retail electric price variance is primarily due to rate actions, including an annual base rate increase of $59 million beginning August 2010 as a result of the settlement of the December 2009 rate case. See Note 2 to the financial statements for further discussion of the rate case settlement.

The securitization transition charge variance is due to the issuance of securitization bonds. In November 2009, Entergy Texas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Texas, issued securitization bonds and with the proceeds purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. The securitization transition charge is offset with a corresponding increase in interest on long-term debt with no impact on net income. See Note 5 to the financial statements for further discussion of the securitization bond issuance.

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The purchased power capacity variance is primarily due to price increases in ongoing purchased power capacity expense and additional capacity purchases.

Gross operating revenues and fuel and purchased power expenses

Gross operating revenues increased primarily due to an increase of $145.6 million in gross wholesale revenues as a result of the addition of new customer contracts and the increase related to volume/weather, as discussed above. The increase was partially offset by a decrease of $59.9 million in fuel cost recovery revenues primarily attributable to lower fuel rates and interim fuel refunds in the first quarter 2010 and the third and fourth quarters 2010. The interim fuel refunds and the PUCT approvals are discussed in Note 2 to the financial statements.

Fuel and purchased power expenses increased primarily due to increases in the average market prices of purchased power and natural gas, substantially offset by a decrease in deferred fuel expenses as the result of lower fuel revenues, as discussed above.

Other Income Statement Variances

2011 Compared to 2010

Other operation and maintenance expenses increased primarily due to:

·	an increase of $8.5 million in transmission expenses due to a billing adjustment recorded in the fourth quarter 2011 related to prior transmission investment equalization costs (for the approximate period of 1996 - 2011) allocable to Entergy Texas under the Entergy System Agreement;

·	an increase of $2.4 million in the over-recovery of energy efficiency revenues; and

·	several individually insignificant items.

The increase was partially offset by the amortization of $11 million of rate case expenses in 2010 and a decrease of $3.9 million in compensation and benefits costs primarily due to a decrease in stock option expense. See Note 2 to the financial statements for further discussion of the rate case settlement.

Taxes other than income taxes increased primarily due to an increase in local franchise taxes as a result of higher city franchise and gross receipts taxes and an increase in ad valorem taxes due to a higher 2011 assessment as compared to 2010, partially offset by lower street rentals.

Depreciation and amortization expenses increased primarily due to an increase in plant in service.

2010 Compared to 2009

Other operation and maintenance expenses increased primarily due to the amortization of $11 million of rate case expenses. See Note 2 to the financial statements for further discussion of the rate case settlement. The increase was partially offset by a charge of $6.8 million in June 2009 resulting from the Hurricane Ike and Hurricane Gustav storm cost recovery settlement with the PUCT. See Note 2 to the financial statements for discussion of this settlement.

Taxes other than income taxes increased primarily due to a provision recorded for sales and use taxes, an increase in local franchise taxes, and an increase in ad valorem taxes as a result of a higher 2010 assessment as compared to 2009, partially offset by lower millage rates.

Other income decreased primarily due to carrying costs recorded in 2009 on storm restoration costs as approved by Texas legislation. See Note 2 to the financial statements for further discussion of Hurricane Ike storm cost recovery filings.

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Interest expense decreased primarily due to lower interest on deferred fuel costs and the pay-down of the debt assumption agreement liability. The decrease was partially offset by the issuance of $546 million in securitization bonds in November 2009.

Income Taxes

The effective income tax rates were 38.0%, 39.0%, and 36.6% for 2011, 2010, and 2009, respectively. See Note 3 to the financial statements for a reconciliation of the federal statutory rate of 35% to the effective income tax rates.

Liquidity and Capital Resources

Cash Flow

Cash flows for the years ended December 31, 2011, 2010, and 2009 were as follows:

		2011	2010	2009
		(In Thousands)

Cash and cash equivalents at beginning of period		$35,342	$200,703	$2,239

Cash flow provided by (used in):
	Operating activities	238,837	43,095	287,533
	Investing activities	(219,783)	(121,439)	(216,649)
	Financing activities	10,893	(87,017)	127,580
	Net increase (decrease) in cash and cash equivalents	29,947	(165,361)	198,464

Cash and cash equivalents at end of period		$65,289	$35,342	$200,703

Operating Activities

Cash flow provided by operating activities increased $195.7 million in 2011 compared to 2010 primarily due to:

·	$73.4 million of fuel cost refunds in 2011 versus $179.5 million of fuel cost refunds in 2010. See Note 2 to the financial statements for discussion of the fuel cost refunds; and

·	income tax refunds of $13.5 million in 2011 compared to income tax payments of $48.7 million in 2010.

Cash flow provided by operating activities decreased $244.4 million in 2010 compared to 2009 primarily due to:

·	the timing of collection of receivables from customers;

income tax payments of $48.7 million in 2010 compared to income tax refunds of $72.3 million in 2009. In 2010, Entergy Texas made tax payments in accordance with the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement. The tax payments resulted from differences between Entergy Texas’s estimated utilization of net operating losses and actual utilization on the 2009 tax return filed in 2010;

·	an $87.8 million fuel cost refund made in the first quarter 2010 and an $77 million fuel cost refund made in the third and fourth quarters 2010; and

·	an increase of $14.7 million in pension contributions. See “Critical Accounting Estimates” below for further discussion of qualified pension and other postretirement benefits funding.

The decrease was partially offset by the absence in 2010 of Hurricane Ike restoration spending that occurred in 2009.

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Investing Activities

Net cash flow used in investing activities increased $98.3 million in 2011 compared to 2010 primarily due to money pool activity.

Increases in Entergy Texas’s receivable from the money pool are a use of cash flow, and Entergy Texas’s receivable from the money pool increased by $49.5 million in 2011 compared to decreasing by $55.6 million in 2010. The money pool is an inter-company borrowing arrangement designed to reduce Entergy’s subsidiaries’ need for external short-term borrowings.

Net cash flow used in investing activities decreased $95.2 million in 2010 compared to 2009 primarily due to money pool activity and a decrease in construction expenditures due to Hurricane Ike spending in 2009, offset by a decrease of $31.5 million in insurance proceeds and increased remittances to the securitization trust account as a result of the issuance of $546 million in securitization bonds in November 2009. See Note 5 to the financial statements for further discussion of the issuance of the securitization bonds.

Decreases in Entergy Texas’s receivable from the money pool are a source of cash flow, and Entergy Texas’s receivable from the money pool decreased by $55.6 million in 2010 compared to increasing by $69.3 million in 2009.

Financing Activities

Entergy Texas’s financing activities provided $10.9 million of cash in 2011 compared to using $87.0 million of cash in 2010 primarily due to:

·	the retirement of $199 million of debt assumption liabilities and securitization bonds in 2010 compared to the retirement of $57.4 million of securitization bonds in 2011; and

·	a decrease of $80.6 million in common equity distributions.

The cash provided was partially offset by the issuance of $200 million of 3.60% Series mortgage bonds in May 2010 compared to the issuance of $75 million of 4.10% Series first mortgage bonds in September 2011.

Entergy Texas’s financing activities used $87 million of cash in 2010 compared to providing $127.6 million of cash in 2009 primarily due to:

·	the issuance of $545.9 million of securitization bonds in November 2009. See Note 5 to the financial statements for additional information regarding the securitization bonds;

·	the issuance of $500 million of 7.125% Series mortgage bonds in January 2009;

·	the issuance of $150 million of 7.875% Series mortgage bonds in May 2009;

·	the issuance of $200 million of 3.60% Series mortgage bonds in May 2010; and

·	the retirement of $199 million of debt assumption liabilities and securitization bonds in 2010 compared to $620 million in 2009.

The use of cash was partially offset by:

·	the repayment of Entergy Texas’s $160 million note payable to Entergy Corporation in January 2009;

·	the repayment of $100 million outstanding on Entergy Texas’s credit facility in February 2009;

·	money pool activity; and

·	a decrease of $33.1 million in common equity distributions.

Decreases in Entergy Texas’s payable to the money pool are a use of cash flow, and Entergy Texas’s payable to the money pool decreased by $50.8 million in 2009.

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Management’s Financial Discussion and Analysis

Capital Structure

Entergy Texas’s capitalization is balanced between equity and debt, as shown in the following table.

	December 31, 2011	December 31, 2010

Debt to capital	65.1%	66.8%
Effect of excluding the securitization bonds	(14.3)%	(16.0)%
Debt to capital, excluding securitization bonds (1)	50.8%	50.8%
Effect of subtracting cash	(1.9)%	(1.0)%
Net debt to net capital, excluding securitization bonds (1)	48.9%	49.8%

(1)	Calculation excludes the securitization bonds, which are non-recourse to Entergy Texas.

Net debt consists of debt less cash and cash equivalents. Debt consists of notes payable and long-term debt, including the currently maturing portion and also including the debt assumption liability. Capital consists of debt and common equity. Net capital consists of capital less cash and cash equivalents. Entergy Texas uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Texas’s financial condition.

Uses of Capital

Entergy Texas requires capital resources for:

·	construction and other capital investments;

·	debt maturities or retirements;

·	working capital purposes, including the financing of fuel and purchased power costs; and

·	dividend and interest payments.

Following are the amounts of Entergy Texas’s planned construction and other capital investments, existing debt and lease obligations (includes estimated interest payments), and other purchase obligations:

	2012	2013-2014	2015-2016	After 2016	Total
	(In Millions)
Planned construction and capital investment (1):
Generation	$84	$92	N/A	N/A	$176
Transmission	45	213	N/A	N/A	258
Distribution	64	141	N/A	N/A	205
Other	9	16	N/A	N/A	25
Total	$202	$462	N/A	N/A	$664
Long-term debt (2)	$90	$198	$496	$1,811	$2,595
Operating leases	$6	$9	$3	$1	$19
Purchase obligations (3)	$92	$118	$101	$160	$471

(1)	Includes approximately $131 million annually for maintenance capital, which is planned spending on routine capital projects that are necessary to support reliability of service, equipment or systems and to support normal customer growth.
(2)	Includes estimated interest payments. Long-term debt is discussed in Note 5 to the financial statements.
(3)	Purchase obligations represent the minimum purchase obligation or cancellation charge for contractual obligations to purchase goods or services. For Entergy Texas, it primarily includes unconditional fuel and purchased power obligations.

In addition to the contractual obligations given above, Entergy Texas expects to contribute approximately $7.7 million to its pension plans and approximately $5.2 million to other postretirement plans in 2012 although the required pension contributions will not be known with more certainty until the January 1, 2012 valuations are completed by April 1, 2012.

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Also in addition to the contractual obligations, Entergy Texas has $7.2 million of unrecognized tax benefits and interest net of unused tax attributes and payments for which the timing of payments beyond 12 months cannot be reasonably estimated due to uncertainties in the timing of effective settlement of tax positions. See Note 3 to the financial statements for additional information regarding unrecognized tax benefits.

Entergy’s Utility supply plan initiative will continue to seek to transform its generation portfolio with new or repowered generation resources. Opportunities resulting from the supply plan initiative, including new projects or the exploration of alternative financing sources, could result in increases or decreases in the capital expenditure estimates given above. The estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints, environmental compliance, market volatility, economic trends, business restructuring, changes in project plans, and the ability to access capital. Management provides more information on long-term debt and preferred stock maturities in Notes 5 and 6 to the financial statements.

As a wholly-owned subsidiary, Entergy Texas pays dividends to Entergy Corporation from its earnings at a percentage determined monthly.

Sources of Capital

Entergy Texas’s sources to meet its capital requirements include:

·	internally generated funds;

·	cash on hand;

·	debt or preferred stock issuances; and

·	bank financing under new or existing facilities.

Entergy Texas may refinance, redeem, or otherwise retire debt prior to maturity, to the extent market conditions and interest and dividend rates are favorable.

All debt and common and preferred stock issuances by Entergy Texas require prior regulatory approval. Debt issuances are also subject to issuance tests set forth in its bond indentures and other agreements. Entergy Texas has sufficient capacity under these tests to meet its foreseeable capital needs.

Entergy Texas’s receivables from or (payables to) the money pool were as follows as of December 31 for each of the following years:

2011	2010	2009	2008
(In Thousands)

$63,191	$13,672	$69,317	($50,794)

See Note 4 to the financial statements for a description of the money pool.

Entergy Texas has a credit facility in the amount of $100 million scheduled to expire in August 2012. No borrowings were outstanding under the facility as of December 31, 2011.

Entergy Texas has obtained short-term borrowing authorization through October 2013 from the FERC under which it may borrow at any one time outstanding, $200 million in the aggregate. See Note 4 to the financial statements for further discussion of Entergy Texas’s short-term borrowing limits. Entergy Texas has also obtained an order from the FERC authorizing long-term securities issuances through July 2013.

Hurricane Ike and Hurricane Gustav

In September 2008, Hurricane Ike caused catastrophic damage to Entergy Texas’s service territory. The storm resulted in widespread power outages, significant damage to distribution, transmission, and generation infrastructure, and the loss of sales during the power outages. Entergy Texas filed an application in April 2009 seeking a determination that $577.5 million of Hurricane Ike and Hurricane Gustav restoration costs are recoverable,

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Management’s Financial Discussion and Analysis

including estimated costs for work to be completed. On August 5, 2009, Entergy Texas submitted to the ALJ an unopposed settlement agreement intended to resolve all issues in the storm cost recovery case. Under the terms of the agreement $566.4 million, plus carrying costs, are eligible for recovery. Insurance proceeds will be credited as an offset to the securitized amount. Of the $11.1 million difference between Entergy Texas’s request and the amount agreed to, which is part of the black box agreement and not directly attributable to any specific individual issues raised, $6.8 million is operation and maintenance expense for which Entergy Texas recorded a charge in the second quarter 2009. The remaining $4.3 million was recorded as utility plant. The PUCT approved the settlement in August 2009, and in September 2009 the PUCT approved recovery of the costs, plus carrying costs, by securitization. See Note 5 to the financial statements for a discussion of the November 2009 issuance of the securitization bonds.

In the third quarter 2009, Entergy settled with its insurer on its Hurricane Ike claim and Entergy Texas received $75.5 million in proceeds (Entergy received a total of $76.5 million).

State and Local Rate Regulation and Fuel-Cost Recovery

The rates that Entergy Texas charges for its services significantly influence its financial position, results of operations, and liquidity. Entergy Texas is regulated and the rates charged to its customers are determined in regulatory proceedings. The PUCT, a governmental agency, is primarily responsible for approval of the rates charged to customers.

Filings with the PUCT

2009 Rate Case

2011 Rate Case

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Fuel and Purchased Power Cost Recovery

In January 2008, Entergy Texas made a compliance filing with the PUCT describing how its 2007 rough production cost equalization receipts under the System Agreement were allocated between Entergy Gulf States, Inc.'s Texas and Louisiana jurisdictions. In December 2008 the PUCT adopted an ALJ proposal for decision recommending an additional $18.6 million allocation to Texas retail customers. Because the PUCT allocation to Texas retail customers is inconsistent with the LPSC allocation to Louisiana retail customers, the PUCT's decision results in trapped costs between the Texas and Louisiana jurisdictions with no mechanism for recovery. Entergy Texas filed with the FERC a proposed amendment to the System Agreement bandwidth formula to specifically calculate the payments to Entergy Gulf States Louisiana and Entergy Texas of Entergy Gulf States, Inc.'s rough production cost equalization receipts for 2007. In May 2009 the FERC issued an order rejecting the proposed amendment. Because of the FERC's order, Entergy Texas recorded the effects of the PUCT's allocation of the additional $18.6 million to Texas retail customers in the second quarter 2009. On an after-tax basis, the charge to earnings was approximately $13.0 million (including interest). The PUCT and FERC decisions are now final.

In May 2009, Entergy Texas filed with the PUCT a request to refund $46.1 million, including interest, of fuel cost recovery over-collections through February 2009. Entergy Texas requested that the proposed refund be made over a four-month period beginning June 2009. Pursuant to a stipulation among the various parties, in June 2009 the PUCT issued an order approving a refund of $59.2 million, including interest, of fuel cost recovery overcollections through March 2009. The refund was made for most customers over a three-month period beginning July 2009.

In October 2009, Entergy Texas filed with the PUCT a request to refund approximately $71 million, including interest, of fuel cost recovery over-collections through September 2009. Entergy Texas requested that the proposed refund be made over a six-month period beginning January 2010. Pursuant to a stipulation among the various parties, the PUCT issued an order approving a refund of $87.8 million, including interest, of fuel cost recovery overcollections through October 2009. The refund was made for most customers over a three-month period beginning January 2010.

Entergy Texas’s November 2011 rate case filing, which is discussed above, also includes a request to reconcile $1.3 billion of fuel and purchased power costs covering the period July 2009 through June 2011.

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Federal Regulation

Industrial and Commercial Customers

Entergy Texas’s large industrial and commercial customers continually explore ways to reduce their energy costs. In particular, cogeneration is an option available to a portion of Entergy Texas’s industrial customer base. Entergy Texas responds by working with industrial and commercial customers and negotiating electric service contracts to provide, under existing rate schedules, competitive rates that match specific customer needs and load profiles. Entergy Texas actively participates in economic development, customer retention, and reclamation activities to increase industrial and commercial demand, from both new and existing customers. Entergy Texas does not currently expect additional significant losses to cogeneration because of the current economics of the electricity markets and Entergy Texas’s marketing efforts in retaining industrial customers.

Environmental Risks

Entergy Texas’s facilities and operations are subject to regulation by various governmental authorities having jurisdiction over air quality, water quality, control of toxic substances and hazardous and solid wastes, and other environmental matters. Management believes that Entergy Texas is in substantial compliance with environmental regulations currently applicable to its facilities and operations. Because environmental regulations are subject to change, future compliance costs cannot be precisely estimated.

Critical Accounting Estimates

The preparation of Entergy Texas’s financial statements in conformity with generally accepted accounting principles requires management to apply appropriate accounting policies and to make estimates and judgments that can have a significant effect on reported financial position, results of operations, and cash flows. Management has identified the following accounting policies and estimates as critical because they are based on assumptions and measurements that involve a high degree of uncertainty, and the potential for future changes in the assumptions and measurements that could produce estimates that would have a material effect on the presentation of Entergy Texas’s financial position or results of operations.

Unbilled Revenue

As discussed in Note 1 to the financial statements, Entergy Texas records an estimate of the revenues earned for energy delivered since the latest customer billing. Each month the estimated unbilled revenue amounts are recorded as revenue and a receivable, and the prior month’s estimate is reversed. The difference between the estimate of the unbilled receivable at the beginning of the period and the end of the period is the amount of unbilled revenue recognized during the period. The estimate recorded is primarily based upon an estimate of customer usage during the unbilled period and the billed price to customers in that month. Therefore, revenue recognized may be affected by the estimated price and usage at the beginning and end of each period and fuel price fluctuations, in addition to changes in certain components of the calculation.

Qualified Pension and Other Postretirement Benefits

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numerous factors including the provisions of the plans, changing employee demographics, and various actuarial calculations, assumptions, and accounting mechanisms. See the “Critical Accounting Estimates” section of Entergy Corporation and Subsidiaries’ Management’s Discussion and Analysis for further discussion. Because of the complexity of these calculations, the long-term nature of these obligations, and the importance of the assumptions utilized, Entergy’s estimate of these costs is a critical accounting estimate.

Cost Sensitivity

The following chart reflects the sensitivity of qualified pension and qualified projected benefit obligation cost to changes in certain actuarial assumptions (dollars in thousands):

Actuarial Assumption	Change in Assumption	Impact on 2011 Qualified Pension Cost	Impact on Qualified Projected Benefit Obligation
	Increase/(Decrease)

Discount rate	(0.25%)	$808	$10,726
Rate of return on plan assets	(0.25%)	$647	-
Rate of increase in compensation	0.25%	$334	$1,830

The following chart reflects the sensitivity of postretirement benefit cost and accumulated postretirement benefit obligation changes in certain actuarial assumptions (dollars in thousands):

Actuarial Assumption	Change in Assumption	Impact on 2011 Postretirement Benefit Cost	Impact on Accumulated Postretirement Benefit Obligation
	Increase/(Decrease)

Health care cost trend	0.25%	$596	$3,969
Discount rate	(0.25%)	$376	$4,520

Each fluctuation above assumes that the other components of the calculation are held constant.

Costs and Funding

Total qualified pension cost for Entergy Texas in 2011 was $4.4 million. Entergy Texas anticipates 2012 qualified pension cost to be $10.4 million. Entergy Texas contributed $18.2 million to its qualified pension plans in 2011. Entergy Texas’s contributions to the pension trust are currently estimated to be approximately $7.7 million in 2012 although the required pension contributions will not be known with more certainty until the January 1, 2012 valuations are completed by April 1, 2012.

Total postretirement health care and life insurance benefit costs for Entergy Texas in 2011 were $4.1 million, including $1.5 million in savings due to the estimated effect of future Medicare Part D subsidies. Entergy Texas expects 2012 postretirement health care and life insurance benefit costs to approximate $6 million, including $1.3 million in savings due to the estimated effect of future Medicare Part D subsidies. Entergy Texas expects to contribute approximately $5.2 million to its other postretirement plans in 2012.

Federal Healthcare Legislation

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Entergy Corporation and Subsidiaries Management’s Discussion and Analysis.

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholder of

Entergy Texas, Inc. and Subsidiaries

Beaumont, Texas

We have audited the accompanying consolidated balance sheets of Entergy Texas, Inc. and Subsidiaries (the “Company”) as of December 31, 2011 and 2010, and the related consolidated income statements, consolidated statements of cash flows, and consolidated statements of changes in common equity (pages 374 through 378 and applicable items in pages 53 through 194) for each of the three years in the period ended December 31, 2011. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of Entergy Texas, Inc. and Subsidiaries as of December 31, 2011 and 2010, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2011, in conformity with accounting principles generally accepted in the United States of America.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands)

OPERATING REVENUES
Electric	$	1,757,199		$	1,690,431		$	1,563,823

OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale		352,022			343,083			449,335
Purchased power		775,067			743,438			584,550
Other operation and maintenance		214,191			209,699			204,524
Taxes other than income taxes		69,329			63,897			55,480
Depreciation and amortization		79,263			76,057			74,035
Other regulatory charges - net		52,307			63,683			44,807
TOTAL		1,542,179			1,499,857			1,412,731

OPERATING INCOME		215,020			190,574			151,092

OTHER INCOME
Allowance for equity funds used during construction		3,781			5,661			5,232
Interest and investment income		5,528			7,222			47,541
Miscellaneous - net		(3,047	)		(3,220	)		544
TOTAL		6,262			9,663			53,317

INTEREST EXPENSE
Interest expense		93,554			95,272			106,163
Allowance for borrowed funds used during construction		(2,609	)		(3,618	)		(2,510	)
TOTAL		90,945			91,654			103,653

INCOME BEFORE INCOME TAXES		130,337			108,583			100,756

Income taxes		49,492			42,383			36,915

NET INCOME	$	80,845		$	66,200		$	63,841

See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands)

OPERATING ACTIVITIES
Net income	$	80,845		$	66,200		$	63,841
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization		79,263			76,057			74,035
Deferred income taxes, investment tax credits, and non-current taxes accrued		56,219			63,418			4,365
Changes in assets and liabilities:
Receivables		(39,640	)		(41,820	)		281,710
Fuel inventory		(12	)		1,085			2,688
Accounts payable		(11,442	)		23,415			(99,483	)
Taxes accrued		11,760			(49,030	)		27,986
Interest accrued		(582	)		3,102			8,473
Deferred fuel costs		(12,766	)		(25,318	)		123,927
Other working capital accounts		42,518			(115,753	)		(95,603	)
Provisions for estimated losses		(296	)		(3,390	)		(4,226	)
Other regulatory assets		(15,611	)		51,637			(187,250	)
Pension and other postretirement liabilities		64,686			(5,998	)		(12,594	)
Other assets and liabilities		(16,105	)		(510	)		99,664
Net cash flow provided by operating activities		238,837			43,095			287,533

INVESTING ACTIVITIES
Construction expenditures		(173,462	)		(162,822	)		(188,277	)
Allowance for equity funds used during construction		3,781			5,661			5,232
Insurance proceeds		-			5,293			36,749
Change in money pool receivable - net		(49,519	)		55,645			(69,317	)
Increase in other investments		-			2,318			-
Remittances to transition charge account		(92,786	)		(89,939	)		(36,999	)
Payments from transition charge account		92,203			62,405			35,963
Net cash flow used in investing activities		(219,783	)		(121,439	)		(216,649	)

FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		74,092			198,435			1,177,819
Retirement of long-term debt		(57,419	)		(199,052	)		(619,945	)
Change in money pool payable - net		-			-			(50,794	)
Repayment of loan from Entergy Corporation		-			-			(160,000	)
Changes in credit borrowings - net		-			-			(100,000	)
Dividends paid:
Common stock		(5,780	)		(86,400	)		(119,500	)
Net cash flow provided by (used in) financing activities		10,893			(87,017	)		127,580

Net increase (decrease) in cash and cash equivalents		29,947			(165,361	)		198,464

Cash and cash equivalents at beginning of period		35,342			200,703			2,239

Cash and cash equivalents at end of period	$	65,289		$	35,342		$	200,703

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid/(received) during the period for:
Interest - net of amount capitalized	$	89,792		$	87,147		$	93,951
Income taxes	$	(13,538	)	$	48,713		$	(72,322	)

See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS

	December 31,
	2011			2010
	(In Thousands)

CURRENT ASSETS
Cash and cash equivalents:
Cash	$	150		$	1,719
Temporary cash investments		65,139			33,623
Total cash and cash equivalents		65,289			35,342
Securitization recovery trust account		41,215			40,632
Accounts receivable:
Customer		68,290			56,358
Allowance for doubtful accounts		(1,461	)		(2,185	)
Associated companies		129,561			53,128
Other		9,573			11,605
Accrued unbilled revenues		41,573			39,471
Total accounts receivable		247,536			158,377
Accumulated deferred income taxes		88,436			44,752
Fuel inventory - at average cost		53,884			53,872
Materials and supplies - at average cost		29,810			28,842
Prepayments and other		15,203			14,856
TOTAL		541,373			376,673

OTHER PROPERTY AND INVESTMENTS
Investments in affiliates - at equity		783			812
Non-utility property - at cost (less accumulated depreciation)		930			1,223
Other		17,969			17,037
TOTAL		19,682			19,072

UTILITY PLANT
Electric		3,338,608			3,205,566
Construction work in progress		90,856			80,096
TOTAL UTILITY PLANT		3,429,464			3,285,662
Less - accumulated depreciation and amortization		1,289,166			1,245,729
UTILITY PLANT - NET		2,140,298			2,039,933

DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Regulatory asset for income taxes - net		129,924			127,046
Other regulatory assets (includes securitization property of $704,896 as of December 31, 2011 and $763,841 as of December 31, 2010)		1,178,067			1,168,960
Long-term receivables - associated companies		31,254			32,596
Other		18,408			19,584
TOTAL		1,357,653			1,348,186

TOTAL ASSETS	$	4,059,006		$	3,783,864

See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY

	December 31,
	2011		2010
	(In Thousands)

CURRENT LIABILITIES
Accounts payable:
Associated companies	$	60,583	$	69,862
Other		69,160		70,325
Customer deposits		38,294		38,376
Taxes accrued		40,311		28,551
Interest accrued		33,095		33,677
Deferred fuel costs		64,664		77,430
Pension and other postretirement liabilities		1,029		1,354
System agreement cost equalization		43,290		-
Other		4,847		4,222
TOTAL		355,273		323,797

NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued		934,990		829,668
Accumulated deferred investment tax credits		19,339		20,936
Other regulatory liabilities		11,710		26,178
Asset retirement cost liabilities		3,870		3,651
Accumulated provisions		5,024		5,320
Pension and other postretirement liabilities		137,735		72,724
Long-term debt (includes securitization bonds of $749,673 as of December 31, 2011 and $807,066 as of December 31, 2010)		1,677,127		1,659,230
Other		14,583		18,070
TOTAL		2,804,378		2,635,777

Commitments and Contingencies

COMMON EQUITY
Common stock, no par value, authorized 200,000,000 shares;
issued and outstanding 46,525,000 shares in 2011 and 2010		49,452		49,452
Paid-in capital		481,994		481,994
Retained earnings		367,909		292,844
TOTAL		899,355		824,290

TOTAL LIABILITIES AND EQUITY	$	4,059,006	$	3,783,864

See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN COMMON EQUITY
For the Years Ended December 31, 2011, 2010, and 2009

	Common Equity
	Common Stock		Paid-in Capital		Retained Earnings			Total
	(In Thousands)

Balance at December 31, 2008	$	49,452	$	481,994	$	368,703		$	900,149
Net income		-		-		63,841			63,841
Common stock dividends		-		-		(119,500	)		(119,500	)
Balance at December 31, 2009	$	49,452	$	481,994	$	313,044		$	844,490
Net income		-		-		66,200			66,200
Common stock dividends		-		-		(86,400	)		(86,400	)
Balance at December 31, 2010	$	49,452	$	481,994	$	292,844		$	824,290
Net income		-		-		80,845			80,845
Common stock dividends		-		-		(5,780	)		(5,780	)
Balance at December 31, 2011	$	49,452	$	481,994	$	367,909		$	899,355

See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON

	2011		2010		2009		2008		2007
	(In Thousands)

Operating revenues	$	1,757,199	$	1,690,431	$	1,563,823	$	2,012,258	$	1,782,923
Net Income	$	80,845	$	66,200	$	63,841	$	57,895	$	58,921
Total assets	$	4,059,006	$	3,783,864	$	3,920,133	$	3,984,771	$	3,606,752
Long-term obligations (1)	$	1,677,127	$	1,659,230	$	1,490,283	$	1,084,368	$	1,103,863

(1) Includes long-term debt (excluding currently maturing debt)

		2011		2010		2009		2008		2007
	(Dollars In Millions)
Electric Operating Revenues:
Residential	$	638	$	559	$	533	$	606	$	544
Commercial		369		321		337		417		364
Industrial		352		305		332		489		414
Governmental		26		23		23		27		24
Total retail		1,385		1,208		1,225		1,539		1,346
Sales for resale:
Associated companies		262		373		294		436		398
Non-associated companies		74		76		10		6		6
Other		36		33		35		31		33
Total	$	1,757	$	1,690	$	1,564	$	2,012	$	1,783
Billed Electric Energy Sales (GWh):
Residential		6,034		5,958		5,453		5,245		5,280
Commercial		4,433		4,271		4,165		4,092		4,085
Industrial		6,102		5,642		5,570		5,948		5,911
Governmental		294		271		258		248		246
Total retail		16,863		16,142		15,446		15,533		15,522
Sales for resale:
Associated companies		4,158		3,758		3,630		3,771		4,366
Non-associated companies		1,258		1,300		231		87		89
Total		22,279		21,200		19,307		19,391		19,977

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SYSTEM ENERGY RESOURCES, INC.

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

System Energy’s principal asset currently consists of a 78.5% ownership interest and 11.5% leasehold interest in Grand Gulf. The capacity and energy from its 90% interest is sold under the Unit Power Sales Agreement to its only four customers, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy’s operating revenues are derived from the allocation of the capacity, energy, and related costs associated with its 90% interest in Grand Gulf pursuant to the Unit Power Sales Agreement. Payments under the Unit Power Sales Agreement are System Energy’s only source of operating revenues.

Results of Operations

Net Income

2011 Compared to 2010

Net income decreased $18.4 million primarily due to an increase in the effective income tax rate. A decrease in operating income was offset by an increase in other income and a decrease in interest expense, which led to a slight increase in income before income taxes. Operating income was lower because of lower rate base compared to 2010. Other income was higher and interest expense was lower primarily because of AFUDC accrued on the Grand Gulf uprate project.

2010 Compared to 2009

Net income increased $33.7 million primarily due to a decrease in the effective income tax rate.

Income Taxes

The effective income tax rates for 2011, 2010, and 2009 were 53.9%, 40.4%, and 66.5%, respectively. The increase in the rate for 2011 is primarily due to an intercompany settle up for federal income taxes for years prior to 2008 which include an allocation of the tax benefit of Entergy Corporation’s expenses to the subsidiaries generating taxable income for the respective years. The effects of various tax positions settled with the IRS pertaining to the 2006/2007 audit require System Energy to pay back prior benefits of the Entergy Corporation’s expenses it received when the benefits were originally allocated based upon the tax return as filed. See Note 3 to the financial statements for a reconciliation of the federal statutory rate of 35.0% to the effective income tax rates.

Liquidity and Capital Resources

Cash Flow

Cash flows for the years ended December 31, 2011, 2010, and 2009 were as follows:

		2011	2010	2009
		(In Thousands)

Cash and cash equivalents at beginning of period		$263,772	$264,482	$102,788

Cash flow provided by (used in):
	Operating activities	430,681	250,405	417,877
	Investing activities	(311,397)	(184,588)	(149,344)
	Financing activities	(197,899)	(66,527)	(106,839)
	Net increase (decrease) in cash and cash equivalents	(78,615)	(710)	161,694

Cash and cash equivalents at end of period		$185,157	$263,772	$264,482

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System Energy Resources, Inc.

Management’s Financial Discussion and Analysis

Operating Activities

Cash flow provided by operating activities increased $180.3 million in 2011 primarily due to income tax refunds of $100.9 million in 2011 compared to income tax payments of $56 million in 2010. In 2011 System Energy received cash refunds in accordance with the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement. The refunds result from a decrease in 2010 taxable income from what was previously estimated because of the recognition of additional repair expenses for tax purposes associated with a tax accounting change filed in 2010 and from the reversal of temporary differences for which System Energy previously made cash tax payments.

Cash flow provided by operations decreased $167.5 million in 2010 primarily due to income tax payments of $56 million in 2010 compared to income tax refunds of $120.4 in 2009, and an increase of $26.6 million in pension contributions. In 2010 System Energy made tax payments in accordance with the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement. The payments resulted from the reversal of temporary differences for which System Energy previously received cash tax benefits and from estimated federal income tax payments for tax year 2010. See “Critical Accounting Estimates” below for a discussion of qualified pension and other postretirement benefits.

Investing Activities

Net cash used in investing activities increased $126.8 million in 2011 primarily due to:

·	The proceeds from the transfer, in the first quarter 2010, of $100.3 million in development costs related to Entergy New Nuclear Development, LLC;

·	An increase in construction expenditures resulting primarily from spending on the power uprate project at Grand Gulf;

·	The repayment in 2010 of $25.6 million by Entergy New Orleans of a note issued in resolution of its bankruptcy proceedings; and

·	money pool activity.

The increase was partially offset by a decrease in nuclear fuel purchases due to the timing of refueling outages.

Increases in System Energy’s receivable from the money pool are a use of cash flow, and System Energy’s receivable from the money pool increased by $22.5 million in 2011 compared to increasing by $7.4 million in 2010. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Net cash used in investing activities increased $35.2 million in 2010 primarily due to an increase of $129.5 million in nuclear fuel purchases due to the timing of refueling outages, and an increase in construction expenditures primarily due to the Grand Gulf power uprate project. The increase was partially offset by:

·	the proceeds from the transfer of $100.3 million in development costs related to Entergy New Nuclear Development, LLC discussed below;

·	money pool activity; and

·	the repayment by Entergy New Orleans of a $25.6 million note issued in resolution of its bankruptcy proceedings.

Increases in System Energy’s receivable from the money pool are a use of cash flow, and System Energy’s receivable from the money pool increased by $7.4 million in 2010 compared to increasing by $47.6 million in 2009.

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System Energy Resources, Inc.

Management’s Financial Discussion and Analysis

Financing Activities

Cash used in financing activities increased $131.4 million in 2011 primarily due to the issuance of $60 million of 5.33% Series G notes by the nuclear fuel company variable interest entity in 2010, the repayment of $38.3 million in commercial paper in 2011 as compared to the issuance of $20.3 million in commercial paper in 2010, and the partial retirement of $40 million of 6.2% pollution control bonds in 2011. The increase was slightly offset by a $24 million decrease in dividend paid on common stock.

Net cash flow used in financing activities decreased $40.3 million in 2010 primarily due to:

·	the issuance in April 2010 of $60 million of 5.33% Series G notes by the nuclear fuel company variable interest entity to finance its fuel procurement activities; and

·	commercial paper issuances by the nuclear fuel company variable interest entity to finance its fuel procurement activities.

The decrease was partially offset by:

·	an increase of $24.9 million in dividends paid on common stock; and

·	an increase of $13.3 million in the January 2010 principal payment made on the Grand Gulf sale-leaseback compared to the January 2009 principal payment.

See Note 5 to the financial statements for details of long-term debt.

Capital Structure

System Energy’s capitalization is balanced between equity and debt, as shown in the following table.

	December 31, 2011	December 31, 2010

Debt to capital	48.3%	51.7%
Effect of subtracting cash	(7.1)%	(9.0)%
Net debt to net capital	41.2%	42.7%

Net debt consists of debt less cash and cash equivalents. Debt consists of capital lease obligations and long-term debt, including the currently maturing portion. Capital consists of debt and common shareholder’s equity. Net capital consists of capital less cash and cash equivalents. System Energy uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating System Energy’s financial condition.

Uses of Capital

System Energy requires capital resources for:

·	construction and other capital investments;

·	debt maturities or retirements;

·	working capital purposes, including the financing of fuel costs; and

·	dividend and interest payments.

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System Energy Resources, Inc.

Management’s Financial Discussion and Analysis

Following are the amounts of System Energy’s planned construction and other capital investments, existing debt and lease obligations (includes estimated interest payments), and other purchase obligations:

	2012	2013-2014	2015-2016	After 2016	Total
	(In Millions)
Planned construction and capital investment (1):
Generation	$316	$74	N/A	N/A	$390
Other	2	4	N/A	N/A	6
Total	$318	$78	N/A	N/A	$396
Long-term debt (2)	$153	$225	$157	$496	$1,031
Purchase obligations (3)	$21	$23	$23	$51	$118

(1)	Includes approximately $19 million annually for maintenance capital, which is planned spending on routine capital projects that are necessary to support reliability of service, equipment, or systems.
(2)	Includes estimated interest payments. Long-term debt is discussed in Note 5 to the financial statements.
(3)	Purchase obligations represent the minimum purchase obligation or cancellation charge for contractual obligations to purchase goods or services. For System Energy, it includes nuclear fuel purchase obligations.

In addition to the contractual obligations given above, System Energy expects to contribute approximately $8.9 million to its pension plans and approximately $4.1 million to its other postretirement plans in 2012 although the required pension contributions will not be known with more certainty until the January 1, 2012 valuations are completed by April 1, 2012.

Also in addition to the contractual obligations, System Energy has $228.6 million of unrecognized tax benefits and interest net of unused tax attributes and payments for which the timing of payments beyond 12 months cannot be reasonably estimated due to uncertainties in the timing of effective settlement of tax positions. See Note 3 to the financial statements for additional information regarding unrecognized tax benefits.

The planned capital investment estimate for System Energy reflects capital required to support the existing business of System Energy. The estimate also includes the costs of System Energy’s planned approximate 178 MW uprate of the Grand Gulf nuclear plant. On November 30, 2009, the MPSC issued a Certificate of Public Convenience and Necessity for implementation of the uprate. A license amendment application was submitted to the NRC in September 2010. After performing more detailed project design, engineering, analysis and major materials purchases, System Energy’s current estimate of the total capital investment to be made in the course of the implementation of the Grand Gulf uprate project is approximately $754 million, including SMEPA’s share. The estimate includes spending on certain major equipment refurbishment and replacement that would have been required over the normal course of the plant’s life even if the uprate were not done. The purpose of performing this major equipment refurbishment and replacement in connection with the uprate is to avoid additional plant outages and construction costs in the future while improving plant reliability. The investment estimate may be revised in the future as System Energy evaluates the progress of the project, including the costs required to install instrumentation in the steam dryer in response to recent guidance from the NRC staff obtained during the review process for certain Requests for Additional Information (RAIs) issued by the NRC in December 2011. The NRC’s review of the project is ongoing. System Energy is responding to the recent RAIs and will seek to minimize potential cost effects or delay, if any, to the Grand Gulf uprate implementation schedule.

System Energy also invested, through its subsidiary Entergy New Nuclear Development, LLC, in initial development costs for potential new nuclear development at the Grand Gulf and River Bend sites, including licensing and design activities. This project is in the early stages, and several issues remain to be addressed over time before significant additional capital would be committed to this project. In addition, Entergy temporarily suspended reviews of the two license applications for the sites and will explore alternative nuclear technologies for this project. In the first quarter 2010 the $100 million in construction work in progress incurred by Entergy New Nuclear Development was transferred to Entergy Gulf States Louisiana, Entergy Louisiana, and Entergy Mississippi.

As a wholly-owned subsidiary, System Energy dividends its earnings to Entergy Corporation at a percentage determined monthly. Currently, all of System Energy’s retained earnings are available for distribution.

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System Energy Resources, Inc.

Management’s Financial Discussion and Analysis

Sources of Capital

System Energy’s sources to meet its capital requirements include:

·	internally generated funds;

·	cash on hand;

·	debt issuances; and

·	bank financing under new or existing facilities.

System Energy may refinance, redeem, or otherwise retire debt prior to maturity, to the extent market conditions and interest and dividend rates are favorable.

All debt and common stock issuances by System Energy require prior regulatory approval. Debt issuances are also subject to issuance tests set forth in its bond indentures and other agreements. System Energy has sufficient capacity under these tests to meet its foreseeable capital needs.

In February 2012, System Energy VIE issued $50 million of 4.02% Series H notes due February 2017. System Energy used the proceeds to purchase additional nuclear fuel.

System Energy has obtained a short-term borrowing authorization from the FERC under which it may borrow, through October 2013, up to the aggregate amount, at any one time outstanding, of $200 million. See Note 4 to the financial statements for further discussion of System Energy’s short-term borrowing limits. System Energy has also obtained an order from the FERC authorizing long-term securities issuances. The current long-term authorization extends through July 2013.

System Energy’s receivables from the money pool were as follows as of December 31 for each of the following years:

2011	2010	2009	2008
(In Thousands)

$120,424	$97,948	$90,507	$42,915

See Note 4 to the financial statements for a description of the money pool.

Nuclear Matters

System Energy owns and operates Grand Gulf. System Energy is, therefore, subject to the risks related to owning and operating a nuclear plant. These include risks from the use, storage, handling and disposal of high-level and low-level radioactive materials, regulatory requirement changes, including changes resulting from events at other plants, limitations on the amounts and types of insurance commercially available for losses in connection with nuclear operations, and technological and financial uncertainties related to decommissioning nuclear plants at the end of their licensed lives, including the sufficiency of funds in decommissioning trusts. In the event of an unanticipated early shutdown of Grand Gulf, System Energy may be required to provide additional funds or credit support to satisfy regulatory requirements for decommissioning.

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System Energy Resources, Inc.

Management’s Financial Discussion and Analysis

Environmental Risks

System Energy’s facilities and operations are subject to regulation by various governmental authorities having jurisdiction over air quality, water quality, control of toxic substances and hazardous and solid wastes, and other environmental matters. Management believes that System Energy is in substantial compliance with environmental regulations currently applicable to its facilities and operations. Because environmental regulations are subject to change, future compliance costs cannot be precisely estimated.

Critical Accounting Estimates

The preparation of System Energy’s financial statements in conformity with generally accepted accounting principles requires management to apply appropriate accounting policies and to make estimates and judgments that can have a significant effect on reported financial position, results of operations, and cash flows. Management has identified the following accounting policies and estimates as critical because they are based on assumptions and measurements that involve a high degree of uncertainty, and there is the potential for future changes in the assumptions and measurements that could produce estimates that would have a material impact on the presentation of System Energy’s financial position or results of operations.

Nuclear Decommissioning Costs

Qualified Pension and Other Postretirement Benefits

Cost Sensitivity

The following chart reflects the sensitivity of qualified pension cost and qualified projected benefit obligation to changes in certain actuarial assumptions (dollars in thousands):

Actuarial Assumption	Change in Assumption	Impact on 2011 Qualified Pension Cost	Impact on Projected Qualified Benefit Obligation
	Increase/(Decrease)

Discount rate	(0.25%)	$795	$9,826
Rate of return on plan assets	(0.25%)	$446	-
Rate of increase in compensation	0.25%	$330	$2,031

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System Energy Resources, Inc.

Management’s Financial Discussion and Analysis

The following chart reflects the sensitivity of postretirement benefit cost and accumulated postretirement benefit obligation to changes in certain actuarial assumptions (dollars in thousands):

Actuarial Assumption	Change in Assumption	Impact on 2011 Postretirement Benefit Cost	Impact on Accumulated Postretirement Benefit Obligation
	Increase/(Decrease)

Health care cost trend	0.25%	$368	$2,141
Discount rate	(0.25%)	$287	$2,441

Each fluctuation above assumes that the other components of the calculation are held constant.

Costs and Funding

Total qualified pension cost for System Energy in 2011was $6.9 million. System Energy anticipates 2012 qualified pension cost to be $11.5 million. System Energy contributed $28.4 million to its qualified pension plans in 2011and expects to contribute approximately $8.9 million in 2012 although the required pension contributions will not be known with more certainty until the January 1, 2012 valuations are completed by April 1, 2012.

Total postretirement health care and life insurance benefit costs for System Energy in 2011 were $4.1 million, including $1.4 million in savings due to the estimated effect of future Medicare Part D subsidies. System Energy expects 2012 postretirement health care and life insurance benefit costs to approximate $5.6 million, including $1.4 million in savings due to the estimated effect of future Medicare Part D subsidies. System Energy anticipates contributions for postretirement health care and life insurance benefits costs to be $4.1 million in 2012.

Federal Healthcare Legislation

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Entergy Corporation and Subsidiaries Management’s Discussion and Analysis.

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholder of

System Energy Resources, Inc.

Jackson, Mississippi

We have audited the accompanying balance sheets of System Energy Resources, Inc. (the “Company”) as of December 31, 2011 and 2010, and the related income statements, statements of cash flows, and statements of changes in common equity (pages 388 through 392 and applicable items in pages 53 through 194) for each of the three years in the period ended December 31, 2011. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

In our opinion, such financial statements present fairly, in all material respects, the financial position of System Energy Resources, Inc. as of December 31, 2011 and 2010, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2011, in conformity with accounting principles generally accepted in the United States of America.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 27, 2012 expressed an unqualified opinion on the Company’s internal control over financial reporting.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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SYSTEM ENERGY RESOURCES, INC.
INCOME STATEMENTS

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands)

OPERATING REVENUES
Electric	$	563,411		$	558,584		$	554,007

OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale		76,353			69,962			63,877
Nuclear refueling outage expenses		16,314			17,398			19,186
Other operation and maintenance		136,495			124,690			120,707
Decommissioning		31,460			31,374			29,451
Taxes other than income taxes		21,425			23,412			24,246
Depreciation and amortization		142,543			138,641			140,056
Other regulatory credits - net		(11,781	)		(12,040	)		(17,525	)
TOTAL		412,809			393,437			379,998

OPERATING INCOME		150,602			165,147			174,009

OTHER INCOME
Allowance for equity funds used during construction		22,359			9,892			12,484
Interest and investment income		8,294			12,639			4,507
Miscellaneous - net		(699	)		(518	)		(1,813	)
TOTAL		29,954			22,013			15,178

INTEREST EXPENSE
Interest expense		48,117			51,912			47,570
Allowance for borrowed funds used during construction		(6,711	)		(3,425	)		(4,192	)
TOTAL		41,406			48,487			43,378

INCOME BEFORE INCOME TAXES		139,150			138,673			145,809

Income taxes		74,953			56,049			96,901

NET INCOME	$	64,197		$	82,624		$	48,908

See Notes to Financial Statements.

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SYSTEM ENERGY RESOURCES, INC.
STATEMENTS OF CASH FLOWS

	For the Years Ended December 31,
	2011			2010			2009
	(In Thousands)

OPERATING ACTIVITIES
Net income	$	64,197		$	82,624		$	48,908
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		229,715			219,552			169,507
Deferred income taxes, investment tax credits, and non-current taxes accrued		14,923			(1,536	)		211,297
Changes in assets and liabilities:
Receivables		(5,512	)		(728	)		(2,296	)
Accounts payable		17,275			(14,351	)		11,574
Taxes accrued and prepaid taxes		160,494			1,327			5,413
Interest accrued		(38,305	)		3,503			2,667
Other working capital accounts		11,260			(15,287	)		11,672
Provisions for estimated losses		-			(2,009	)		(16	)
Other regulatory assets		10,874			(4,948	)		(4,824	)
Pension and other postretirement liabilities		34,474			29,797			3,440
Other assets and liabilities		(68,714	)		(47,539	)		(39,465	)
Net cash flow provided by operating activities		430,681			250,405			417,877

INVESTING ACTIVITIES
Construction expenditures		(234,753	)		(156,766	)		(90,778	)
Proceeds from the transfer of development costs		-			100,280			-
Allowance for equity funds used during construction		22,359			9,892			12,484
Nuclear fuel purchases		(59,755	)		(129,504	)		-
Proceeds from sale of nuclear fuel		12,420			-			180
Changes in other investments		-			25,560			-
Proceeds from nuclear decommissioning trust fund sales		203,444			322,789			392,959
Investment in nuclear decommissioning trust funds		(232,636	)		(349,398	)		(416,597	)
Change in money pool receivable - net		(22,476	)		(7,441	)		(47,592	)
Net cash flow used in investing activities		(311,397	)		(184,588	)		(149,344	)

FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		-			55,385			-
Retirement of long-term debt		(78,161	)		(41,715	)		(28,440	)
Changes in credit borrowings - net		(38,264	)		20,003			-
Dividends paid:
Common stock		(76,000	)		(100,200	)		(75,300	)
Other		(5,474	)		-			(3,099	)
Net cash flow used in financing activities		(197,899	)		(66,527	)		(106,839	)

Net increase (decrease) in cash and cash equivalents		(78,615	)		(710	)		161,694

Cash and cash equivalents at beginning of period		263,772			264,482			102,788

Cash and cash equivalents at end of period	$	185,157		$	263,772		$	264,482

SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized	$	40,719		$	35,540		$	48,005
Income taxes	$	(100,889	)	$	55,963		$	(120,352	)

See Notes to Financial Statements.

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SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
ASSETS

	December 31,
	2011		2010
	(In Thousands)

CURRENT ASSETS
Cash and cash equivalents:
Cash	$	30,961	$	903
Temporary cash investments		154,196		262,869
Total cash and cash equivalents		185,157		263,772
Accounts receivable:
Associated companies		172,943		147,180
Other		7,294		5,070
Total accounts receivable		180,237		152,250
Materials and supplies - at average cost		86,333		84,077
Deferred nuclear refueling outage costs		9,479		22,627
Prepaid taxes		-		68,039
Prepayments and other		1,111		1,142
TOTAL		462,317		591,907

OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds		423,409		387,876
TOTAL		423,409		387,876

UTILITY PLANT
Electric		3,438,424		3,362,422
Property under capital lease		491,023		489,175
Construction work in progress		357,826		210,536
Nuclear fuel		157,967		155,282
TOTAL UTILITY PLANT		4,445,240		4,217,415
Less - accumulated depreciation and amortization		2,518,190		2,417,811
UTILITY PLANT - NET		1,927,050		1,799,604

DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Regulatory asset for income taxes - net		124,777		126,642
Other regulatory assets		287,796		296,715
Other		20,016		21,326
TOTAL		432,589		444,683

TOTAL ASSETS	$	3,245,365	$	3,224,070

See Notes to Financial Statements.

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SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
LIABILITIES AND EQUITY

	December 31,
	2011		2010
	(In Thousands)

CURRENT LIABILITIES
Currently maturing long-term debt	$	110,163	$	33,740
Short-term borrowings		-		38,264
Accounts payable:
Associated companies		8,032		6,520
Other		63,331		38,447
Taxes accrued		92,455		-
Accumulated deferred income taxes		3,428		8,508
Interest accrued		17,776		56,081
Other		2,591		2,258
TOTAL		297,776		183,818

NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued		652,418		617,012
Accumulated deferred investment tax credits		57,865		54,755
Other regulatory liabilities		214,745		201,364
Decommissioning		445,352		452,782
Pension and other postretirement liabilities		139,719		105,245
Long-term debt		636,885		796,728
Other		42		-
TOTAL		2,147,026		2,227,886

Commitments and Contingencies

COMMON EQUITY
Common stock, no par value, authorized 1,000,000 shares;
issued and outstanding 789,350 shares in 2011 and 2010		789,350		789,350
Retained earnings		11,213		23,016
TOTAL		800,563		812,366

TOTAL LIABILITIES AND EQUITY	$	3,245,365	$	3,224,070

See Notes to Financial Statements.

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SYSTEM ENERGY RESOURCES, INC.
STATEMENTS OF CHANGES IN COMMON EQUITY
For the Years Ended December 31, 2011, 2010, and 2009

	Common Equity
	Common Stock		Retained Earnings			Total
	(In Thousands)

Balance at December 31, 2008	$	789,350	$	66,984		$	856,334
Net income		-		48,908			48,908
Common stock dividends		-		(75,300	)		(75,300	)
Balance at December 31, 2009	$	789,350	$	40,592		$	829,942
Net income		-		82,624			82,624
Common stock dividends		-		(100,200	)		(100,200	)
Balance at December 31, 2010	$	789,350	$	23,016		$	812,366
Net income		-		64,197			64,197
Common stock dividends		-		(76,000	)		(76,000	)
Balance at December 31, 2011	$	789,350	$	11,213		$	800,563

See Notes to Financial Statements.

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SYSTEM ENERGY RESOURCES, INC.
SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON

	2011		2010		2009		2008		2007
	(Dollars In Thousands)

Operating revenues	$	563,411	$	558,584	$	554,007	$	528,998	$	553,193
Net Income	$	64,197	$	82,624	$	48,908	$	91,067	$	136,081
Total assets	$	3,245,365	$	3,224,070	$	3,135,651	$	2,945,390	$	2,858,760
Long-term obligations (1)	$	636,885	$	796,728	$	728,253	$	832,697	$	824,824
Electric energy sales (GWh)		9,293		8,692		9,898		8,475		8,440

(1) Includes long-term debt (excluding currently maturing debt) and noncurrent capital lease obligations.

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Item 2. Properties

Information regarding the registrant’s properties is included in Part I. Item 1. - Business under the sections titled “Utility - Property and Other Generation Resources” and “Entergy Wholesale Commodities - Property” in this report.

Item 3. Legal Proceedings

Details of the registrant’s material environmental regulation and proceedings and other regulatory proceedings and litigation that are pending or those terminated in the fourth quarter of 2011 are discussed in Part I. Item 1. - Business under the sections titled “Retail Rate Regulation”, “Environmental Regulation”, and “Litigation” and "Impairment of Long-Lived Assets" in Note 1 to the financial statements in this report.

Item 4. Mine Safety Disclosures

Not applicable.

EXECUTIVE OFFICERS OF ENTERGY CORPORATION

Executive Officers

Name	Age	Position	Period
J. Wayne Leonard (a)	61	Chairman of the Board of Entergy Corporation	2006-Present
		Chief Executive Officer and Director of Entergy Corporation	1999-Present

Richard J. Smith (a)	60	President, Entergy Wholesale Commodity Business of Entergy Corporation	2010-Present
		President and Chief Operating Officer of Entergy Corporation	2007-2010
		Group President, Utility Operations of Entergy Corporation, Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans	2001-2007
		Director of Entergy Arkansas, Entergy Gulf States, Entergy Louisiana and Entergy Mississippi	2001-2007

Gary J. Taylor (a)(b)	58	Group President, Utility Operations of Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi and Entergy Texas	2007-Present
		Director of Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi and Entergy Texas	2007-Present
		Director of Entergy New Orleans	2008-Present
		Executive Vice President and Chief Nuclear Officer of Entergy Corporation	2004-2007
		Director, President and Chief Executive Officer of System Energy	2003-2007

Leo P. Denault (a)	52	Executive Vice President and Chief Financial Officer of Entergy Corporation	2004-Present
		Director of Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi and System Energy	2004-Present
		Director of Entergy Texas	2007-Present
		Director of Entergy New Orleans	2011-Present

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Name	Age	Position	Period
Mark T. Savoff (a)	55	Executive Vice President and Chief Operating Officer of Entergy Corporation	2010-Present
		Executive Vice President, Operations of Entergy Corporation	2004-2010
		Director of Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana and Entergy Mississippi	2004-Present
		Director of Entergy Texas	2007-Present
		Director of Entergy New Orleans	2011-Present
		Executive Vice President of Entergy Services, Inc.	2003-Present

Roderick K. West (a)	43	Executive Vice President and Chief Administrative Officer of Entergy Corporation	2010-Present
		President and Chief Executive Officer of Entergy New Orleans	2007-2010
		Director of Entergy New Orleans	2005-2011
		Director, Metro Distribution Operation of Entergy Services, Inc.	2005-2006

E. Renae Conley (a)	54	Executive Vice President, Human Resources and Administration of Entergy Corporation	2011-Present
		Executive Vice President of Entergy Corporation	2010-2011
		Director of Entergy Gulf States Louisiana and Entergy Louisiana	2000-2010
		President and Chief Executive Officer of Entergy Gulf States Louisiana and Entergy Louisiana	2000-2010

John T. Herron (a)	58	President and Chief Executive Officer Nuclear Operations/ Chief Nuclear Officer of Entergy Corporation	2009-Present
		Executive Vice President and Chief Nuclear Officer of Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana and Entergy Texas	2010-Present
		President, Chief Executive Officer and Director of System Energy	2009-Present
		Senior Vice President, Nuclear Operations	2007-2009
		Senior Vice President, Chief Operating Officer of Entergy Nuclear Northeast	2003-2007

Robert D. Sloan (c)	64	Executive Vice President, General Counsel and Secretary of Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy	2004-2012
		Executive Vice President, General Counsel and Secretary of Entergy Texas	2007-2012

Theodore H. Bunting, Jr. (a)	53	Senior Vice President and Chief Accounting Officer of Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas and System Energy	2007-Present
		Acting principal financial officer of Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans and Entergy Texas	2008-Present
		Vice President and Chief Financial Officer, Nuclear Operations of System Energy	2004-2007

Marcus V. Brown (a)(d)	50	Senior Vice President and General Counsel of Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas and System Energy	2012-Present

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Name	Age	Position	Period
		Vice President and Deputy General Counsel of Entergy Services, Inc.	2009-2012
		Associate General Counsel of Entergy Services, Inc.	2007-2009

Terry R. Seamons (e)	70	Senior Vice President, Organizational Development	2011-2012
		Senior Vice President - Human Resources and Administration of Entergy Corporation	2007-2011
		Vice President and Managing Director of RHR, International	1984-2007

(a)	In addition, this officer is an executive officer and/or director of various other wholly owned subsidiaries of Entergy Corporation and its operating companies.
(b)	Mr. Taylor has advised Entergy that he intends to retire from the positions indicated effective May 31, 2012.
(c)	Mr. Sloan served as Executive Vice President, General Counsel and Secretary of Entergy Corporation through January 27, 2012 and in the other positions indicated through February 3, 2012. Through February 3, 2012, Mr. Sloan also served as an executive officer and/or director of various other wholly owned subsidiaries of Entergy Corporation and its operating companies.
(d)	Mr. Brown has served as Senior Vice President and General Counsel of Entergy Corporation from January 27, 2012 and as Senior Vice President and General Counsel of Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas and System Energy since February 3, 2012.
(e)	Mr. Seamons retired from Entergy effective January 2012. Prior to his retirement, Mr. Seamons was an executive officer and/or director of various other wholly owned subsidiaries of Entergy Corporation and its operating companies.

Each officer of Entergy Corporation is elected yearly by the Board of Directors.

PART II

Item 5. Market for Registrants’ Common Equity and Related Stockholder Matters

Entergy Corporation

The shares of Entergy Corporation’s common stock are listed on the New York Stock and Chicago Stock Exchanges under the ticker symbol ETR.

The high and low prices of Entergy Corporation’s common stock for each quarterly period in 2011 and 2010 were as follows:

	2011		2010
	High	Low	High	Low
	(In Dollars)

First	74.50	64.72	83.09	75.25
Second	70.40	65.15	84.33	71.28
Third	69.14	57.60	80.80	70.35
Fourth	74.00	62.66	77.90	68.65

Consecutive quarterly cash dividends on common stock were paid to stockholders of Entergy Corporation in 2011 and 2010. Quarterly dividends of $0.83 per share were paid in 2011. In 2010, a dividend of $0.75 per share was paid in the first quarter and dividends of $0.83 per share were paid in the last three quarters.

As of January 31, 2012, there were 35,096 stockholders of record of Entergy Corporation.

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Unregistered Sales of Equity Securities and Use of Proceeds

Issuer Purchases of Equity Securities (1)

Period	Total Number of Shares Purchased	Average Price Paid per Share	Total Number of Shares Purchased as Part of a Publicly Announced Plan	Maximum $ Amount of Shares that May Yet be Purchased Under a Plan (2)

10/01/2011-10/31/2011	-	$-	-	$350,052,918
11/01/2011-11/30/2011	-	$-	-	$350,052,918
12/01/2011-12/31/2011	-	$-	-	$350,052,918
Total	-	$-	-

In accordance with Entergy’s stock-based compensation plans, Entergy periodically grants stock options to key employees, which may be exercised to obtain shares of Entergy’s common stock. According to the plans, these shares can be newly issued shares, treasury stock, or shares purchased on the open market. Entergy’s management has been authorized by the Board to repurchase on the open market shares up to an amount sufficient to fund the exercise of grants under the plans. In October 2010 the Board granted authority for an additional $500 million share repurchase program. The amount of share repurchases under these programs may vary as a result of material changes in business results or capital spending or new investment opportunities.

(1)	See Note 12 to the financial statements for additional discussion of the stock-based compensation plans.
(2)	Maximum amount of shares that may yet be repurchased does not include an estimate of the amount of shares that may be purchased to fund the exercise of grants under the stock-based compensation plans.

Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy

There is no market for the common stock of Entergy Corporation’s wholly owned subsidiaries. Cash dividends on common stock paid by the Registrant Subsidiaries during 2011 and 2010, were as follows:

	2011	2010
	(In Millions)

Entergy Arkansas	$117.8	$173.4
Entergy Gulf States Louisiana	$302.0	$124.3
Entergy Louisiana	$358.2	$-
Entergy Mississippi	$3.3	$43.4
Entergy New Orleans	$42.0	$47.0
Entergy Texas	$5.8	$86.4
System Energy	$76.0	$100.2

Information with respect to restrictions that limit the ability of the Registrant Subsidiaries to pay dividends is presented in Note 7 to the financial statements.

Item 6. Selected Financial Data

Refer to “SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON OF ENTERGY CORPORATION AND SUBSIDIARIES, ENTERGY ARKANSAS, INC. AND SUBSIDIARIES, ENTERGY GULF STATES LOUISIANA, L.L.C., ENTERGY LOUISIANA, LLC, ENTERGY MISSISSIPPI, INC., ENTERGY NEW ORLEANS, INC., ENTERGY TEXAS, INC. AND SUBSIDIARIES, and SYSTEM ENERGY RESOURCES, INC.” which follow each company’s financial statements in this report, for information with respect to selected financial data and certain operating statistics.

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Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Refer to “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS OF ENTERGY CORPORATION AND SUBSIDIARIES, ENTERGY ARKANSAS, INC. AND SUBSIDIARIES, ENTERGY GULF STATES, LOUISIANA, L.L.C., ENTERGY LOUISIANA, LLC, ENTERGY MISSISSIPPI, INC., ENTERGY NEW ORLEANS, INC., ENTERGY TEXAS, INC. AND SUBSIDIARIES, and SYSTEM ENERGY RESOURCES, INC.”

Item 7A. Quantitative and Qualitative Disclosures About Market Risk

Refer to “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS OF ENTERGY CORPORATION AND SUBSIDIARIES - Market and Credit Risk Sensitive Instruments.”

Item 8. Financial Statements and Supplementary Data

Refer to “TABLE OF CONTENTS - Entergy Corporation, Entergy Arkansas, Inc., Entergy Gulf States Louisiana, L.L.C., Entergy Louisiana, LLC, Entergy Mississippi, Inc., Entergy New Orleans, Inc., Entergy Texas, Inc., and System Energy Resources, Inc.”

Item 9. Changes In and Disagreements With Accountants On Accounting and Financial Disclosure

No event that would be described in response to this item has occurred with respect to Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, or System Energy.

Item 9A. Controls and Procedures

Disclosure Controls and Procedures

As of December 31, 2011, evaluations were performed under the supervision and with the participation of Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy (individually “Registrant” and collectively the “Registrants”) management, including their respective Principal Executive Officers (PEO) and Principal Financial Officers (PFO). The evaluations assessed the effectiveness of the Registrants’ disclosure controls and procedures. Based on the evaluations, each PEO and PFO has concluded that, as to the Registrant or Registrants for which they serve as PEO or PFO, the Registrant’s or Registrants’ disclosure controls and procedures are effective to ensure that information required to be disclosed by each Registrant in reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in Securities and Exchange Commission rules and forms; and that the Registrant’s or Registrants’ disclosure controls and procedures are also effective in reasonably assuring that such information is accumulated and communicated to the Registrant’s or Registrants’ management, including their respective PEOs and PFOs, as appropriate to allow timely decisions regarding required disclosure.

Internal Control over Financial Reporting

(Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

The managements of Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy (individually “Registrant” and collectively the “Registrants”) are responsible for establishing and maintaining adequate internal control over financial reporting for the Registrants. Each Registrant’s internal control system is designed to provide reasonable assurance regarding the preparation and fair presentation of each Registrant’s financial statements presented in accordance with generally accepted accounting principles.

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All internal control systems, no matter how well designed, have inherent limitations. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.

Each Registrant’s management assessed the effectiveness of each Registrant’s internal control over financial reporting as of December 31, 2011. In making this assessment, each management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in Internal Control - Integrated Framework.

Based on each management’s assessment and the criteria set forth by COSO, each Registrant’s management believes that each Registrant maintained effective internal control over financial reporting as of December 31, 2011.

The Registrants’ registered public accounting firm has issued an attestation report on each Registrant’s internal control over financial reporting.

Changes in Internal Controls over Financial Reporting

Under the supervision and with the participation of the Registrants’ management, including their respective PEOs and PFOs, the Registrants evaluated changes in internal control over financial reporting that occurred during the quarter ended December 31, 2011 and found no change that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

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Attestation Report of Registered Public Accounting Firm

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of

Entergy Corporation and Subsidiaries

New Orleans, Louisiana

We have audited the internal control over financial reporting of Entergy Corporation and Subsidiaries (the “Corporation”) as of December 31, 2011, based on criteria established in Internal Control —Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Corporation’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Corporation’s internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company’s internal control over financial reporting is a process designed by, or under the supervision of, the company’s principal executive and principal financial officers, or persons performing similar functions, and effected by the company’s board of directors, management, and other personnel to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, the Corporation maintained, in all material respects, effective internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control —Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements as of and for the year ended December 31, 2011 of the Corporation and our report dated February 27, 2012 expressed an unqualified opinion on those consolidated financial statements.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of

Entergy Arkansas, Inc. and Subsidiaries

Little Rock, Arkansas

We have audited the internal control over financial reporting of Entergy Arkansas, Inc. and Subsidiaries (the “Company”) as of December 31, 2011, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements as of and for the year ended December 31, 2011 of the Company and our report dated February 27, 2012 expressed an unqualified opinion on those consolidated financial statements.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Members of

Entergy Gulf States Louisiana, L.L.C.

Baton Rouge, Louisiana

We have audited the internal control over financial reporting of Entergy Gulf States Louisiana, L.L.C. (the “Company”) as of December 31, 2011, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the financial statements as of and for the year ended December 31, 2011 of the Company and our report dated February 27, 2012 expressed an unqualified opinion on those financial statements.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Members of

Entergy Louisiana, LLC and Subsidiaries

Baton Rouge, Louisiana

We have audited the internal control over financial reporting of Entergy Louisiana, LLC and Subsidiaries (the “Company”) as of December 31, 2011, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements as of and for the year ended December 31, 2011 of the Company and our report dated February 27, 2012 expressed an unqualified opinion on those consolidated financial statements.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of

Entergy Mississippi, Inc.

Jackson, Mississippi

We have audited the internal control over financial reporting of Entergy Mississippi, Inc. (the “Company”) as of December 31, 2011, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of

Entergy New Orleans, Inc.

New Orleans, Louisiana

We have audited the internal control over financial reporting of Entergy New Orleans, Inc. (the “Company”) as of December 31, 2011, based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2011, based on the criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholder of

Entergy Texas, Inc. and Subsidiaries

Beaumont, Texas

We have audited the internal control over financial reporting of Entergy Texas, Inc. and Subsidiaries (the “Company”) as of December 31, 2011, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements as of and for the year ended December 31, 2011 of the Company and our report dated February 27, 2012 expressed an unqualified opinion on those consolidated financial statements.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholder of

System Energy Resources, Inc.

Jackson, Mississippi

We have audited the internal control over financial reporting of System Energy Resources, Inc. (the “Company”) as of December 31, 2011, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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PART III

Item 10. Directors and Executive Officers of the Registrants (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans and Entergy Texas)

Information required by this item concerning directors of Entergy Corporation is set forth under the heading “Item 1 – Election of Directors” contained in the Proxy Statement of Entergy Corporation, to be filed in connection with its Annual Meeting of Stockholders to be held May 4, 2012, and is incorporated herein by reference.

All officers and directors listed below held the specified positions with their respective companies as of the date of filing this report, unless otherwise noted.

Name	Age	Position	Period

ENTERGY ARKANSAS, INC.

Directors

Hugh T. McDonald	53	President and Chief Executive Officer of Entergy Arkansas	2000-Present
		Director of Entergy Arkansas	2000-Present

Leo P. Denault		See information under the Entergy Corporation Officers Section in Part I.
Mark T. Savoff		See information under the Entergy Corporation Officers Section in Part I.
Gary J. Taylor		See information under the Entergy Corporation Officers Section in Part I.

Officers

Marcus V. Brown		See information under the Entergy Corporation Officers Section in Part I.
Theodore H. Bunting, Jr.		See information under the Entergy Corporation Officers Section in Part I.
E. Renae Conley		See information under the Entergy Corporation Officers Section in Part I.
Leo P. Denault		See information under the Entergy Corporation Officers Section in Part I.
John T. Herron		See information under the Entergy Corporation Officers Section in Part I.
J. Wayne Leonard		See information under the Entergy Corporation Officers Section in Part I.
Hugh T. McDonald		See information under the Entergy Arkansas Directors Section above.
Mark T. Savoff		See information under the Entergy Corporation Officers Section in Part I.
Terry R. Seamons		See information under the Entergy Corporation Officers Section in Part I.
Robert D. Sloan		See information under the Entergy Corporation Officers Section in Part I.
Richard J. Smith		See information under the Entergy Corporation Officers Section in Part I.
Gary J. Taylor		See information under the Entergy Corporation Officers Section in Part I.
Roderick K. West		See information under the Entergy Corporation Officers Section in Part I.

ENTERGY GULF STATES LOUISIANA, L.L.C.

Directors

William M. Mohl	52	Director of Entergy Gulf States Louisiana and Entergy Louisiana	2010-Present
		President and Chief Executive Officer of Entergy Gulf States Louisiana and Entergy Louisiana	2010-Present
		Vice President, System Planning of Entergy Services, Inc.	2007-2010
		Vice President, Commercial Operations of Entergy Services, Inc.	2005-2007

Leo P. Denault		See information under the Entergy Corporation Officers Section in Part I.
Mark T. Savoff		See information under the Entergy Corporation Officers Section in Part I.
Gary J. Taylor		See information under the Entergy Corporation Officers Section in Part I.

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Officers

Marcus V. Brown		See information under the Entergy Corporation Officers Section in Part I.
Theodore H. Bunting, Jr.		See information under the Entergy Corporation Officers Section in Part I.
E. Renae Conley		See information under the Entergy Corporation Officers Section in Part I.
Leo P. Denault		See information under the Entergy Corporation Officers Section in Part I.
John T. Herron		See information under the Entergy Corporation Officers Section in Part I.
J. Wayne Leonard		See information under the Entergy Corporation Officers Section in Part I.
William M. Mohl		See information under the Entergy Gulf States Louisiana Directors Section above.
Mark T. Savoff		See information under the Entergy Corporation Officers Section in Part I.
Terry R. Seamons		See information under the Entergy Corporation Officers Section in Part I.
Robert D. Sloan		See information under the Entergy Corporation Officers Section in Part I.
Richard J. Smith		See information under the Entergy Corporation Officers Section in Part I.
Gary J. Taylor		See information under the Entergy Corporation Officers Section in Part I.
Roderick K. West		See information under the Entergy Corporation Officers Section in Part I.

ENTERGY LOUISIANA, LLC

Directors

William M. Mohl		See information under the Entergy Gulf States Louisiana Directors Section above.
Leo P. Denault		See information under the Entergy Corporation Officers Section in Part I.
Mark T. Savoff		See information under the Entergy Corporation Officers Section in Part I.
Gary J. Taylor		See information under the Entergy Corporation Officers Section in Part I.

Officers

Marcus V. Brown		See information under the Entergy Corporation Officers Section in Part I.
Theodore H. Bunting, Jr.		See information under the Entergy Corporation Officers Section in Part I.
E. Renae Conley		See information under the Entergy Corporation Officers Section in Part I.
Leo P. Denault		See information under the Entergy Corporation Officers Section in Part I.
John T. Herron		See information under the Entergy Corporation Officers Section in Part I.
J. Wayne Leonard		See information under the Entergy Corporation Officers Section in Part I.
William M. Mohl		See information under the Entergy Gulf States Louisiana Directors Section above.
Mark T. Savoff		See information under the Entergy Corporation Officers Section in Part I.
Terry R. Seamons		See information under the Entergy Corporation Officers Section in Part I.
Robert D. Sloan		See information under the Entergy Corporation Officers Section in Part I.
Richard J. Smith		See information under the Entergy Corporation Officers Section in Part I.
Gary J. Taylor		See information under the Entergy Corporation Officers Section in Part I.
Roderick K. West		See information under the Entergy Corporation Officers Section in Part I.

ENTERGY MISSISSIPPI, INC.

Directors

Haley R. Fisackerly	46	President and Chief Executive Officer of Entergy Mississippi	2008-Present
		Director of Entergy Mississippi	2008-Present
		Vice President, Nuclear Government Affairs of Entergy Services, Inc.	2007-2008
		Vice President, Customer Service of Entergy Mississippi	2002-2007

Leo P. Denault		See information under the Entergy Corporation Officers Section in Part I.
Mark T. Savoff		See information under the Entergy Corporation Officers Section in Part I.
Gary J. Taylor		See information under the Entergy Corporation Officers Section in Part I.

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Officers

Marcus V. Brown		See information under the Entergy Corporation Officers Section in Part I.
Theodore H. Bunting, Jr.		See information under the Entergy Corporation Officers Section in Part I.
E. Renae Conley		See information under the Entergy Corporation Officers Section in Part I.
Leo P. Denault		See information under the Entergy Corporation Officers Section in Part I.
Haley R. Fisackerly		See information under the Entergy Mississippi Directors Section above.
John T. Herron		See information under the Entergy Corporation Officers Section in Part I.
J. Wayne Leonard		See information under the Entergy Corporation Officers Section in Part I.
Mark T. Savoff		See information under the Entergy Corporation Officers Section in Part I.
Terry R. Seamons		See information under the Entergy Corporation Officers Section in Part I.
Robert D. Sloan		See information under the Entergy Corporation Officers Section in Part I.
Richard J. Smith		See information under the Entergy Corporation Officers Section in Part I.
Gary J. Taylor		See information under the Entergy Corporation Officers Section in Part I.
Roderick K. West		See information under the Entergy Corporation Officers Section in Part I.

ENTERGY NEW ORLEANS, INC.

Directors

Charles L. Rice, Jr.	47	President and Chief Executive Officer of Entergy New Orleans	2010-Present
		Director of Entergy New Orleans	2010-Present
		Director, Utility Strategy of Entergy Services, Inc.	2009-2010
		Law Partner in the firm of Barrasso, Usdin, Kupperman, Freeman & Sarver, L.L.C.	2005-2009

Leo P. Denault		See information under the Entergy Corporation Officers Section in Part I.
Mark T. Savoff		See information under the Entergy Corporation Officers Section in Part I.
Gary J. Taylor		See information under the Entergy Corporation Officers Section in Part I.

Officers

Marcus V. Brown		See information under the Entergy Corporation Officers Section in Part I.
Theodore H. Bunting, Jr.		See information under the Entergy Corporation Officers Section in Part I.
E. Renae Conley		See information under the Entergy Corporation Officers Section in Part I.
Leo P. Denault		See information under the Entergy Corporation Officers Section in Part I.
John T. Herron		See information under the Entergy Corporation Officers Section in Part I.
J. Wayne Leonard		See information under the Entergy Corporation Officers Section in Part I.
Charles L. Rice, Jr.		See information under the Entergy New Orleans Directors Section above.
Mark T. Savoff		See information under the Entergy Corporation Officers Section in Part I.
Terry R. Seamons		See information under the Entergy Corporation Officers Section in Part I.
Robert D. Sloan		See information under the Entergy Corporation Officers Section in Part I.
Richard J. Smith		See information under the Entergy Corporation Officers Section in Part I.
Gary J. Taylor		See information under the Entergy Corporation Officers Section in Part I.
Roderick K. West		See information under the Entergy Corporation Officers Section in Part I.

ENTERGY TEXAS, INC.

Directors

Joseph F. Domino	63	Director of Entergy Texas	2007-Present
		President and Chief Executive Officer of Entergy Texas	2007-Present
		Director of Entergy Gulf States	1999-2007
		President and Chief Executive Officer - TX of Entergy Gulf States	1998-2007

Leo P. Denault		See information under the Entergy Corporation Officers Section in Part I.
Mark T. Savoff		See information under the Entergy Corporation Officers Section in Part I.
Gary J. Taylor		See information under the Entergy Corporation Officers Section in Part I.

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Officers

Marcus V. Brown		See information under the Entergy Corporation Officers Section in Part I.
Theodore H. Bunting, Jr.		See information under the Entergy Corporation Officers Section in Part I.
E. Renae Conley		See information under the Entergy Corporation Officers Section in Part I.
Leo P. Denault		See information under the Entergy Corporation Officers Section in Part I.
Joseph F. Domino		See information under the Entergy Texas Directors Section above.
John T. Herron		See information under the Entergy Corporation Officers Section in Part I.
J. Wayne Leonard		See information under the Entergy Corporation Officers Section in Part I.
Mark T. Savoff		See information under the Entergy Corporation Officers Section in Part I.
Terry R. Seamons		See information under the Entergy Corporation Officers Section in Part I.
Robert D. Sloan		See information under the Entergy Corporation Officers Section in Part I.
Richard J. Smith		See information under the Entergy Corporation Officers Section in Part I.
Gary J. Taylor		See information under the Entergy Corporation Officers Section in Part I.
Roderick K. West		See information under the Entergy Corporation Officers Section in Part I.

Each director and officer of the applicable Entergy company is elected yearly to serve by the unanimous consent of the sole stockholder with the exception of the directors and officers of Entergy Gulf States Louisiana, L.L.C. and Entergy Louisiana, LLC, who are elected yearly to serve by the unanimous consent of the sole common membership owners, EGS Holdings, Inc. and Entergy Louisiana Holdings, respectively. Entergy Corporation’s directors are elected annually at the annual meeting of shareholders. Entergy Corporation’s officers are elected at the annual meeting of the Board of Directors.

Corporate Governance Guidelines and Committee Charters

Each of the Audit, Corporate Governance and Personnel Committees of Entergy Corporation’s Board of Directors operates under a written charter. In addition, the full Board has adopted Corporate Governance Guidelines. Each charter and the guidelines are available through Entergy’s website (www.entergy.com) or upon written request.

Audit Committee of the Entergy Corporation Board

The following directors are members of the Audit Committee of Entergy Corporation’s Board of Directors:

Steven V. Wilkinson (Chairman)

Maureen S. Bateman

Stuart L. Levenick

Blanche L. Lincoln

All Audit Committee members are independent. For purposes of independence of members of the Audit Committee, an independent director also may not accept directly or indirectly any consulting, advisory or other compensatory fee from Entergy or be affiliated with Entergy as defined in SEC rules. All Audit Committee members possess the level of financial literacy and accounting or related financial management expertise required by the NYSE rules. Steven V. Wilkinson qualifies as an “audit committee financial expert,” as that term is defined in the SEC rules.

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Code of Ethics

The Board of Directors has adopted a Code of Business Conduct and Ethics for Members of the Board of Directors. The code is available through Entergy’s website (www.entergy.com) or upon written request. The Board has also adopted a Code of Business Conduct and Ethics for Employees that includes Special Provision Relating to Principal Executive Officer and Senior Financial Officers. The Code of Business Conduct and Ethics for Employees is to be read in conjunction with Entergy’s omnibus code of integrity under which Entergy operates called the Code of Entegrity as well as system policies. All employees are required to abide by the Codes. Non-bargaining employees are required to acknowledge annually that they understand and abide by the Code of Entegrity. The Code of Business Conduct and Ethics for Employees and the Code of Entegrity are available through Entergy’s website (www.entergy.com) or upon written request.

Source of Nominations to the Board of Directors; Nominating Procedure

The Corporate Governance Committee has adopted a policy on consideration of potential director nominees. The Committee will consider nominees from a variety of sources, including nominees suggested by shareholders, executive officers, fellow board members, or a third party firm retained for that purpose. It applies the same procedures to all nominees regardless of the source of the nomination.

Any party wishing to make a nomination should provide a written resume of the proposed candidate, detailing relevant experience and qualifications, as well as a list of references. The Committee will review the resume and may contact references. It will decide based on the resume and references whether to proceed to a more detailed investigation. If the Committee determines that a more detailed investigation of the candidate is warranted, it will invite the candidate for a personal interview, conduct a background check on the candidate, and assess the ability of the candidate to provide any special skills or characteristics identified by the Committee or the Board.

Section 16(a) Beneficial Ownership Reporting Compliance

Information called for by this item concerning the directors and officers of Entergy Corporation is set forth in the Proxy Statement of Entergy Corporation to be filed in connection with its Annual Meeting of Stockholders to be held on May 4, 2012, under the heading “Section 16(a) Beneficial Ownership Reporting Compliance”, which information is incorporated herein by reference.

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Item 11. Executive Compensation

ENTERGY CORPORATION

Information concerning the directors and officers of Entergy Corporation is set forth in the Proxy Statement under the headings "Compensation Discussion and Analysis," "Executive Compensation Tables," "Nominees for the Board of Directors," and "Non-Employee Director Compensation," all of which information is incorporated herein by reference.

ENTERGY ARKANSAS, ENTERGY GULF STATES LOUISIANA, ENTERGY LOUISIANA, ENTERGY MISSISSIPPI, ENTERGY NEW ORLEANS AND ENTERGY TEXAS

COMPENSATION DISCUSSION AND ANALYSIS

Introduction

In this section, the salaries and other compensation elements paid in 2011 to the Chief Executive Officers ("CEOs"), the Principal Financial Officer ("PFO"), the three other most highly compensated executive officers other than the CEO and PFO (collectively, the "Named Executive Officers") of each of Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans and Entergy Texas (the "Subsidiaries") are discussed and analyzed. Entergy believes the executive pay programs described herein and in the accompanying tables have played a material role in its ability to drive strong financial results and to attract and retain a highly experienced and successful management team. The purpose of this section is to provide investors with material information necessary to understand the compensation policies for the Named Executive Officers. This section should be read in combination with the more detailed compensation tables and other data presented elsewhere in this report. For information regarding the compensation of the named executive officers of Entergy Corporation, see the Proxy Statement of Entergy Corporation.

The Named Executive Officers are identified in the Summary Compensation Table immediately following this Compensation Discussion and Analysis. Mr. Leonard, Mr. Denault and Mr. Taylor also serve as executive officers of Entergy Corporation. Mr. Leonard, Mr. Denault and Mr. Taylor do not receive additional compensation for serving as Named Executive Officers of the Subsidiaries. For more information about the officers of the Subsidiaries, see Part III, Item 10 of this report.

Executive Compensation Best Practices

On an ongoing basis, with the assistance of the Personnel Committee’s independent executive compensation consultant, the Personnel Committee reviews and evaluates Entergy’s overall approach to its executive compensation programs. It undertakes this review to ensure that Entergy’s programs continue to be in line with best practices of other companies in the industry as well as other Fortune 500 companies. As a result of this process, in the past two years the Personnel Committee has:

Eliminated “gross up” payments by Entergy with respect to excise taxes due on the payment of severance benefits to the named executive officers in the case of a change in control. See “Benefits, Perquisites, Agreements and Post-Termination Plans - Retention Agreements and Other Compensation Arrangements.”

·	Adopted a “clawback” policy providing for the recoupment by the Company of incentive compensation in certain circumstances. See “Compensation Program Administration - Executive Compensation Governance.”

·	Adopted a “double trigger” (requiring both a change in control and an involuntary job loss or substantial diminution of duties) for the acceleration of awards under the 2007 and 2011 Equity Ownership and Long-Term Cash Incentive Plans.

·	Adopted a policy prohibiting hedging transactions in Entergy’s common stock by any officer, director or employee. See “Compensation Program Administration - Executive Compensation Governance.”

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Reduced the maximum payout under the Long-Term Performance Unit Program (for top quartile performance) from 250% to 200% of target beginning with the 2011-2013 performance period, combined with an increase in the minimum payout (for third quartile performance) from 10% to 25% of target; there continues to be no payout for bottom quartile performance.

Modified the form of payout for the Long-Term Performance Unit Program, beginning with the 2012- 2014 performance period, to provide that participants will receive their awards in shares of Entergy common stock rather than in cash, with officers required to retain these shares until they satisfy their stock ownership requirements.

·	Increased the portion of long-term compensation that is derived from performance units from 50% to 60% and decreased the portion that is derived from restricted stock and stock option grants to 40%.

·	Eliminated club dues as a perquisite for the members of the Office of Chief Executive and eliminated gross-up payments on perquisites, except for relocation benefits.

·	Discontinued financial counseling as a perquisite for all executive officers, with the value of this discontinued perquisite not being replaced in the executive’s compensation.

Adopted a policy that prohibits Entergy Corporation or its affiliates from engaging the independent compensation consultant that provides executive and director compensation services to the Personnel and Corporate Governance Committees or its affiliates to provide other services to Entergy with an aggregate value in excess of $120,000 in any year. In 2011, the independent consultant to the Committees did not provide any services to Entergy beyond consulting to the Personnel Committee.

The Personnel Committee also considered in 2011, and will consider in the future, the results of the vote of the shareholders on the annual advisory vote on executive compensation. Given the approximately 97% level of support for Entergy’s executive compensation at the 2011 Annual Meeting, the Committee believes that Entergy’s shareholders are generally very satisfied with the pay practices and the Committee did not make any change to Entergy Corporation’s executive compensation program in response to this advisory vote.

2011 Performance and Compensation

Pay for Performance Philosophy. Entergy’s compensation programs for Named Executive Officers are based on a philosophy of pay-for-performance which is embodied in the design of the annual and long-term incentive plans. The annual incentive plan incentivizes and rewards the achievement of operational and financial metrics that are deemed by the Board to be consistent with the overall goals and strategic direction that the Board has set for Entergy. For 2011, these metrics were earnings per share and operating cash flow. The long-term incentive plan was comprised for many years of options and performance unit awards, and in 2011, Entergy added restricted stock awards to the program. The value of these instruments to the executive is directly tied to the performance of the stock price, thereby aligning the interests of the executives and the stockholders.

2011 Performance and Significant Achievements. The businesses delivered strong financial and operational performance in 2011, achieving record as reported earnings per share for the seventh year in a row and strong operating cash flow, despite substantially lagging our peer group in total shareholder return. We believe the efforts in 2011 also have positioned the Company for future success, as reflected in the following significant achievements and recognitions:

·	Achieved record as reported earnings of $7.55 per share and operating cash flow of approximately $3.1 billion;

·	Returned to shareholders nearly $800 million through dividends and net share repurchases;

·	Proposed the transfer of control of the utility operating companies’ transmission assets to the Midwest Independent System Operator Regional Transmission Organization after a comprehensive review and analysis indicated up to $1.4 billion in potential net customer savings over the first 10 years;

·	Entered into agreements for the spin-off and merger with ITC Holdings Corp. of the Company’s transmission business;

·	Obtained 20-year license renewal from the Nuclear Regulatory Commission for Vermont Yankee nuclear facility;

·	Acquired the Rhode Island State Energy Center combined cycle gas turbine (CCGT) plant;

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·	Completed the acquisition of the Acadia power station with full cost recovery;

·	Executed agreements and made appropriate regulatory filings to support the acquisitions of the Hinds and Hot Spring generating facilities and the Ninemile 6 new build CCGT project;

·	Completed securitization for costs associated with the Little Gypsy project;

·	Successfully resolved formula rate plans;

·	Maintained reliability of bulk electric system through 2011 ice events, tornadoes and record flooding;

·	Retained an evaluation in the ‘excellence’ category compared to peers for our Pilgrim and Vermont Yankee nuclear facilities, making a total of five plants in Entergy’s nuclear fleet currently with this evaluation;

·	Hedged over 29 TWh of future nuclear energy production;

·	Completed record runs at our Pilgrim and Cooper nuclear facilities;

·	Included on the Dow Jones Sustainability North America Index, marking the tenth consecutive year on either the DJSI World Index or DJSI North America Index, or both; and

·	Received multiple awards and recognition for economic development, community relations, corporate citizenship, climate protection, customer service and nuclear practices.

Application of Pay-for-Performance Philosophy. Pay outcomes for the Named Executive Officers during 2011 clearly demonstrated the application of the pay-for-performance philosophy. The annual incentive program is tied to the financial performance through the Entergy Achievement Multiplier (the performance metric used to determine awards under the Annual Incentive Plan), which is determined based on Entergy’s success in achieving the earnings per share and operating cash flow goals. Entergy substantially exceeded the earnings per share goal of $6.60 in 2011 by $0.95 per share, while falling short of the operating cash flow goal of $3.35 billion by $221 million. This resulted in an Entergy Achievement Multiplier of 128% of the executive’s target annual incentive plan compensation, with the Chief Executive Officer receiving an award equal to 154% of his base salary and the other Named Executive Officers each receiving awards equal to between 50% and 90% of their base salaries. For additional information regarding the Annual Incentive Compensation program see “Short-Term Compensation - Non-Equity Incentive Plans (Cash Bonus).”

This contrasts with the performance under the long-term incentives, which are directly tied to total shareholder return. Under the Long-Term Performance Unit Program, Entergy measures performance over a three year period by assessing Entergy's total shareholder return in relation to the total shareholder return of the companies included in the Philadelphia Utility Index, with payouts under the plan tied directly to Entergy’s performance in relation to the other companies in the index over the performance period. Relative total shareholder return is used as the measure of performance under this program because it encourages the executives to deliver superior shareholder value in relation to Entergy’s peers and rewards not just stock appreciation, but also the ability to deliver significant dividends to shareholders. Notwithstanding the strong overall operational and financial performance in 2011, the total shareholder return was in the bottom quartile of the Philadelphia Utility Index for the 2009-2011 performance period, which resulted in a zero payout for the performance units granted in 2009. Moreover, many of the stock options granted to the Named Executive Officers in recent years have no intrinsic value, due to declines in Entergy’s stock price since they were granted. For additional information regarding the long-term compensation program, see “Long-Term Compensation - Performance Unit Program.”

Objectives of the Executive Compensation Program

·	The greatest part of the compensation of the Named Executive Officers should be in the form of "at risk" performance-based compensation in order to focus the executives on the achievement of superior results.

The executive compensation programs are designed to ensure that a significant percentage of the total compensation of the Named Executive Officers is contingent on achievement of performance goals that drive total shareholder return and result in increases in Entergy Corporation's common stock price. For example, each of the annual cash incentive and long-term performance unit programs is designed to pay out only if Entergy achieves pre-established performance goals. If minimum established performance goals are not achieved, no payouts are made under the incentive programs. Assuming achievement of these performance goals at target levels, approximately 80% of the annual target total compensation (excluding non-qualified supplemental retirement income) of Entergy Corporation's Chief Executive Officer is at risk because it is performance-based compensation and the remaining 20% is

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represented by base salary. For Mr. Denault and Mr. Taylor, assuming achievement of performance goals at the target levels, approximately 65% of the annual target total compensation (excluding non-qualified supplemental retirement income) is at risk because it is performance-based compensation with the remaining 35% represented by base salary. For substantially all of the other Named Executive Officers, assuming achievement of performance goals at the target levels, at least 50% of the annual target total compensation (excluding non-qualified supplemental retirement income) is at risk because it is performance-based compensation with the remaining 50% represented by base salary. Entergy Corporation's Chief Executive Officer's total compensation is at greater risk than the other Named Executive Officers, reflecting both market practice and acknowledging the leadership role of the Chief Executive Officer in setting company policies and strategies.

·	A substantial portion of the Named Executive Officers' compensation should be delivered in the form of equity awards.

To align the economic interests of the Named Executive Officers with the shareholders of Entergy Corporation, Entergy believes a substantial portion of its total compensation should be in the form of equity-based awards. In 2011, awards were granted in the form of restricted stock, stock options and performance units. Stock options and restricted stock generally will be subject to time-based vesting. Performance units pay out only if Entergy Corporation achieves specified performance targets with the amount of payout contingent on the level of performance achieved and Entergy’s common stock price. These awards focus and reward executive officers on building shareholder value. Further, beginning with the 2012-2014 performance period, the performance unit program will help to provide an even greater portion of the officer’s total compensation in equity, as these awards will be settled in shares of Entergy common stock rather than in cash.

·	The compensation programs of Entergy Corporation and the Subsidiaries should enable the companies to attract, retain and motivate executive talent by offering competitive compensation packages.

It is in the shareholders' best interests that Entergy Corporation and the Subsidiaries attract and retain talented executives by offering compensation packages that are competitive. Entergy Corporation's Personnel Committee has sought to develop compensation programs that deliver total target compensation in the aggregate at approximately the 50th percentile of the market data.

The Starting Point

To develop a competitive compensation program, the Personnel Committee annually reviews base salary and other compensation data from two sources:

Survey Data: The Committee uses published and private compensation survey data to develop marketplace compensation levels for executive officers. The data, which is compiled by the Committee's independent compensation consultant, compares the current compensation opportunities provided to each of the executive officers against the compensation opportunities provided to executives holding similar positions at companies with corporate revenues consistent with the revenues of Entergy Corporation. For non-industry specific positions such as a chief financial officer, the Committee reviews general industry data for total cash compensation (base salary and annual incentive). For management positions that are industry-specific such as Group President, Utility Operations, the Committee reviews data from energy services companies for total cash compensation. However, for long-term incentives, all positions are reviewed relative to utility market data. The survey data reviewed by the Committee covers approximately 400 public and private companies in general industry and approximately over 60 investor-owned companies in the energy services sector. In evaluating compensation levels against the survey data, the Committee considers only the aggregated survey data. The identity of the companies comprising the survey data is not disclosed to, or considered by, the Committee in its decision-making process and, thus, is not considered material by the Committee.

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The Committee uses the survey data to develop compensation opportunities that deliver total target compensation at approximately the 50th percentile of the surveyed companies. This survey data is used as the primary data for purposes of determining target compensation. For this purpose, the Committee reviews the results of the survey data (organized in tabular format) comparing each of the Named Executive Officer's compensation relative to the 25th, 50th (or median) and 75th percentile of the surveyed companies. The Committee considers its objectives to have been met if Entergy Corporation's Chief Executive Officer and the eight (8) other executive officers who constitute what is referred to as the Office of the Chief Executive each have a target compensation package that falls within the range of 85 - 115 percentile of the 50th percentile of the companies in the survey data. In 2011, in the aggregate the target compensation of all of the Named Executive Officers fell within this range. Actual compensation received by an individual officer may be above or below the 50th percentile based on an individual officer's skills, performance and responsibilities, Entergy Corporation performance and internal pay equity.

Proxy Analysis: Although the survey data described above is the primary data source used in determining compensation, the Committee reviews data derived from proxy statements as an additional point of analysis. The proxy data is used to compare the compensation levels of the named executive officers against the compensation levels of the corresponding top five highest paid executive officers from the companies in the Philadelphia Utilities Index. The Personnel Committee does not target Entergy’s executive compensation elements against the companies included in the index, but rather, uses the proxy analysis to evaluate the reasonableness of the compensation program. The proxy market data compare Entergy executive officers to other proxy officers based on pay rank without regard to roles and responsibilities. These companies are:

· AES Corporation	· Exelon Corporation
· Ameren Corporation	· FirstEnergy Corporation
· American Electric Power Co. Inc.	· NextEra Energy
· CenterPoint Energy Inc.	· Northeast Utilities
· Consolidated Edison Inc.	· PG&E Corporation
· Dominion Resources Inc.	· Progress Energy, Inc.
· DTE Energy Company	· Public Service Enterprise Group, Inc.
· Duke Energy Corporation	· Southern Company
· Edison International	· Xcel Energy

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Elements of the Compensation Program

The major components of the 2011 executive compensation program are presented below:

Entergy’s executive compensation package consists of a combination of short-term and long-term compensation elements. Short-term compensation included base pay and annual cash incentive awards and long-term compensation included stock options, restricted stock and performance units. All of the incentive plans are linked to Entergy’s financial and stock performance or its total shareholder return in relation to its peers. The executive compensation program is approved by Entergy’s Personnel Committee, which consists entirely of independent board members.

The executive compensation programs reflect a balanced compensation approach to incentivizing and rewarding performance by combining a market-based base salary with reasonable annual and long-term incentive compensation programs. These incentive compensation programs are designed to reward the executive officers if they attain specified annual and long-term goals while taking an appropriate level of risk.

Compensation decisions for each executive officer are made after taking into account all elements of the officer’s compensation. In making compensation decisions, Entergy applies the same compensation policies to all of the executive officers; however, the application of these policies results in different compensation amounts to individual executive officers because of: (i) differences in roles and responsibilities; (ii) differences in market-based compensation levels for specific officer positions; (iii) the assessment of individual performance; (iv) internal equity; and (v) variations in business unit performance.

Short-Term Compensation

·	Base Salary

Base salary is a component of each Named Executive Officer's compensation package because the Personnel Committee believes it is appropriate that some portion of the compensation that is provided to these officers is stable. Also, base salary remains the most common form of payment throughout all industries. Its use ensures a competitive compensation package for the Named Executive Officers.

The Committee (in the case of Mr. Leonard, Mr. Denault and Mr. Taylor) determine the base salaries for these Named Executive Officers, including whether to grant annual merit increases in base salary based on the following factors:

·	Entergy Corporation, business unit and individual performance during the prior year;

·	Market data;

·	Internal pay equity and the executive pay structure;

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·	The Committee's assessment of other elements of compensation provided to the Named Executive Officers; and

·	Entergy’s Chief Executive Officer’s recommendations for the Named Executive Officers other than himself.

The use of "internal pay equity" in setting merit increases assists the Committee in determining whether a change in an executive officer's role and responsibilities relative to other executive officers requires an adjustment in the officer's salary. The Committee has not established any predetermined formula against which the base salary of one Named Executive Officer is measured against another officer or employee.

In 2011, the Named Executive Officers received merit increases in their base salaries in the range of 2 to 4 percent. The increases in base salary were made in light of current economic conditions and the projected growth in executive salaries in 2011 based on general industry surveys obtained from human resources consulting firms.

The following table sets forth the 2011 base salaries for the Named Executive Officers. Changes in base salaries were effective in April of each of the years shown.

Named Executive Officer	2010 Base Salary	2011 Base Salary
J. Wayne Leonard	$1,291,500	$1,323,800
Leo P. Denault	$630,000	$ 655,200
Gary J. Taylor	$570,000	$ 592,800
Theodore H. Bunting, Jr.	$350,448	$ 359,209
Joseph F. Domino	$317,754	$ 324,104
Haley R. Fisackerly	$275,000	$ 283,250
Hugh T. McDonald	$322,132	$ 330,185
William M. Mohl	$325,000	$ 335,550
Charles L. Rice, Jr.	$240,000	$ 247,200

Mr. Leonard’s base salary is larger than the other Named Executive Officers because of his leadership role in setting company policies and strategic planning and reflects market practice for salaries for chief executive officers of similarly sized companies.

·	Non-Equity Incentive Plan (Cash Bonus)

Performance-based incentives are included in the Named Executive Officers' compensation packages because Entergy believes performance-based incentives encourage the Named Executive Officers to pursue objectives consistent with the overall goals and strategic direction that the Entergy Board has set for Entergy Corporation and the Subsidiaries. Annual incentive plans are commonly used by companies in a variety of industry sectors to compensate their executive officers for achieving financial and operational goals.

The Named Executive Officers participate in a performance-based cash bonus plan known as the Executive Annual Incentive Plan or Executive Incentive Plan. Under the plan, Entergy uses a performance metric known as the Entergy Achievement Multiplier to determine the percentage of target annual plan awards that will be paid each year to each Named Executive Officer. Each year the Personnel Committee reviews the performance measures used to determine the Entergy Achievement Multiplier. In December 2010, the Personnel Committee decided to retain the performance measures used in 2010. Accordingly, the 2011 performance measures used to determine the Entergy Achievement Multiplier were consolidated earnings per share and operating cash flow, with each measure weighted equally. The Committee selected these performance measures because:

·	earnings per share and operating cash flow have both a correlative and causal relationship to shareholder value over the long-term;

·	earnings per share and operating cash flow targets are aligned with externally-communicated goals; and

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·	earnings per share and operating cash flow results are readily available in earning releases and SEC filings.

In addition, these measures are used by a number of other companies, including the companies in the Philadelphia Utility Index, as components of their incentive programs. For example, approximately 72 percent of the industry peer group companies use earnings per share as an incentive measure.

The Committee sets minimum, target and maximum achievement levels under the Executive Incentive Plan. Payouts for performance between minimum and target achievement levels and between target and maximum levels are calculated using straight line interpolation. If Entergy does not achieve its minimum achievement levels, no payout occurs under the Executive Incentive Plan. In general, the Committee seeks to establish target achievement levels such that the relative difficulty of achieving the target level is consistent from year to year. Over the past five years ending with 2011, the average Entergy Achievement Multiplier was 136% of target.

In December 2010, the Committee set the 2011 target awards for incentives to be paid for 2011 under the Executive Incentive Plan. As a percentage of base salary, the target awards for certain of Entergy named executive officers were set as follows: J. Wayne Leonard, CEO of Entergy Corporation (120%); Leo P. Denault, Executive Vice President and Chief Financial Officer (70%); and Gary J. Taylor, Group President Utility Operations (70%). The Committee based its decision on the target awards for Mr. Denault and Mr. Taylor on the recommendation of Entergy’s Chief Executive Officer.

In setting these target awards, the Personnel Committee considered several factors, including:

·	Analysis provided by the Committee's independent compensation consultant as to compensation practices at the industry peer group companies and the general market for companies the size of Entergy Corporation;

·	Competitiveness of the compensation plans and Entergy’s ability to attract and retain top executive talent;

·	The individual performance of each Entergy named executive officer (other than the Chief Executive Officer of Entergy Corporation) as evaluated by the Chief Executive Officer of Entergy Corporation;

·	Target bonus levels in the market for comparable positions;

·	The desire to ensure that a substantial portion of total compensation is performance-based;

·	The relative importance of the short-term performance goals established pursuant to the Executive Incentive Plan;

·	Internal pay equity and the executive pay structure;

·	The Committee's assessment of other elements of compensation provided to the Named Executive Officers; and

·	Entergy’s Chief Executive Officer’s recommendations for the Named Executive Officers other than himself.

The Committee established a higher target percentage for Mr. Leonard compared to the other Named Executive Officers to reflect the following factors:

·	Market practices that compensate chief executive officers at greater potential compensation levels with more "pay at risk" than other executive officers.

The Personnel Committee's assessment of Mr. Leonard's strong performance based on the Board's annual performance evaluation, in which the Board reviews and assesses Mr. Leonard's performance based on critical factors such as: leadership, strategic planning, financial results, succession planning, communications with all of Entergy’s stakeholders, external relations with the communities and industries in which Entergy Corporation operates and his relationship with the Board.

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The target awards for the other Named Executive Officers were set as follows: Joseph F. Domino, CEO - Entergy Texas (50%); Hugh T. McDonald, CEO - Entergy Arkansas (50%); Haley Fisackerly, CEO - Entergy Mississippi (40%); William M. Mohl (60%), CEO - Entergy Gulf States and Entergy Louisiana; Charles L. Rice, Jr. (40%), CEO - Entergy New Orleans and Theodore H. Bunting, Jr. - Principal Accounting Officer - the Subsidiaries (60%).

The target awards for the Named Executive Officers (other than Entergy named executive officers) were set by their respective supervisors (subject to ultimate approval of Entergy’s Chief Executive Officer) who allocated a potential incentive pool established by the Personnel Committee among various of their direct and indirect reports. In setting the target awards, the supervisor took into account considerations similar to those used by the Personnel Committee in setting the target awards for Entergy’s Named Executive Officers.

Target awards are set based on an executive officer’s current position and executive management level within the Entergy organization. Executive management levels at Entergy range from Level 1 thorough Level 4. Mr. Denault and Mr. Taylor hold positions in Level 2 whereas Mr. Bunting and Mr. Mohl hold positions in Level 3 and Mr. Domino, Mr. Fisackerly, Mr. McDonald and Mr. Rice hold positions in Level 4. Accordingly, their respective incentive targets differ one from another based on the external market data developed by the Committee’s independent compensation consultant and the other factors noted above.

In December 2010, the Committee determined the Executive Incentive Plan targets to be used for purposes of establishing annual bonuses for 2011. The Committee’s determination of the target levels was made after full Board review of management’s 2011 financial plan for Entergy Corporation, upon recommendation of the Finance Committee, and after the Committee’s determination that the established targets aligned with Entergy Corporation’s anticipated 2011 financial performance as reflected in the financial plan. The targets established to measure management performance against as reported results were:

	Minimum	Target	Maximum
Earnings Per Share ($)	$6.10	$6.60	$7.10
Operating Cash Flow ($ in Billions)	$2.97	$3.35	$3.70

In January 2012, after reviewing earnings per share and operating cash flow results against the performance objectives in the above table, the Committee determined that Entergy Corporation had exceeded as reported earnings per share target of $6.60 by $0.95 in 2011 while falling short of the operating cash flow goal of $3.35 billion by $221 million in 2011. In accordance with the terms of the Annual Incentive Plan, in January 2012, the Personnel Committee certified the 2012 Entergy Achievement Multiplier at 128% of target.

Under the terms of the Management Effectiveness Program, the Entergy Achievement Multiplier is automatically increased by 25 percent for the members of the Office of the Chief Executive if the pre-established underlying performance goals established by the Personnel Committee are satisfied at the end of the performance period, subject to the Personnel Committee's discretion to adjust the automatic multiplier downward or eliminate it altogether. In accordance with Section 162(m) of the Internal Revenue Code, the multiplier which Entergy refers to as the Management Effectiveness Factor is intended to provide the Committee a mechanism to take into consideration specific achievement factors relating to the overall performance of Entergy Corporation. In January 2012, the Committee eliminated the Management Effectiveness Factor with respect to the 2011 incentive awards, reflecting the Personnel Committee's determination that the Entergy Achievement Multiplier, in and of itself without the Management Effectiveness Factor, was consistent with the performance levels achieved by management.

The annual incentive awards for the Named Executive Officers (other than Mr. Leonard, Mr. Denault and Mr. Taylor) are awarded from an incentive pool approved by the Committee. From this pool, each Named Executive Officer’s supervisor determines the annual incentive payment based on the Entergy Achievement Multiplier. The supervisor has the discretion to increase or decrease the multiple used to determine an incentive award based on individual and business unit performance. The incentive awards are subject to the ultimate approval of Entergy’s Chief Executive Officer.

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The following table shows the Executive Incentive Plan payments as a percentage of base salary for 2011 based on an Entergy Achievement Multiplier of 128% as well as the incentive awards for each Named Executive Officer:

Named Executive Officer	Target	Percentage Base Salary	2011 Annual Incentive Award
J. Wayne Leonard	120%	154%	$2,033,356
Leo P. Denault	70%	90%	$ 587,059
Gary J. Taylor	70%	90%	$ 531,148
Theodore H. Bunting, Jr.	60%	111%	$ 400,000
Joseph F. Domino	50%	66%	$ 215,000
Haley R. Fisackerly	40%	53%	$ 150,000
Hugh T. McDonald	50%	65%	$ 210,000
William M. Mohl	60%	79%	$ 265,000
Charles L. Rice, Jr.	40%	53%	$ 130,000

Nuclear Retention Plan

Some of Entergy’s executive officers, including Mr. Taylor, participate in a retention plan for officers and other leaders with special expertise in the nuclear industry. The Committee authorized this retention plan to attract and retain management talent in the nuclear power field, a field that requires unique technical and other expertise that is in great demand in the utility industry. This type of retention plan is not an uncommon practice among companies that operate nuclear power plants. Mr. Taylor’s participation in the plan covers a three-year period that began on January 1, 2009 and terminated with the January 2012 payment. In January 2010, 2011 and 2012, in accordance with the terms and conditions of the plan, Mr. Taylor received a cash bonus equal to 30% of his base salary as of January 1, 2009. Mr. Taylor’s participation in the plan (with respect to the period covered and percentage of base salary paid) is consistent with the level of participation of other employees who participate in the Plan. Mr. Taylor has advised Entergy Corporation that he intends to resign from his position as Group President, Utility Operations, effective May 31, 2012.

Long-Term Compensation

Entergy’s goal for long-term incentive compensation is to focus and reward executive officers for building shareholder value and to increase the executive officers’ ownership in Entergy Corporation common stock. In the long-term incentive programs, Entergy uses a mix of performance units, restricted stock and stock options. Performance units reward the Named Executive Officers on the basis of total shareholder return, which is a measure of stock appreciation, dividend payments and stock price relative to the companies in the Philadelphia Utility Index. Restricted stock ties the executive officers’ long-term financial interest to the long-term financial interests of the shareholders. Stock options provide a direct incentive for increasing the price of Entergy Corporation common stock. In addition, restricted stock units have occasionally been awarded for retention purposes or to offset forfeited compensation in order to attract officers and managers from other companies. The target value of long-term incentive compensation granted is allocated 60% to performance units and 40% to a combination, equally divided, of stock options and restricted stock, all based on their grant date values.

Each of the performance units, shares of restricted stock and stock options granted to the Named Executive Officers in 2011 were awarded under the 2007 Equity Ownership and Long Term Cash Incentive Plan of Entergy Corporation, which is referred to as the 2007 Equity Ownership Plan. At Entergy’s 2011 Annual Meeting, Entergy’s shareholders approved the 2011 Equity Ownership and Long Term Cash Incentive Plan or 2011 Equity Ownership Plan. Any equity award granted after that date will be granted under the 2011 Equity Ownership Plan.

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·	Performance Unit Program

Entergy issues performance unit awards to the Named Executive Officers under its Long-Term Performance Unit Program. Historically, each performance unit equals the cash value of one share of Entergy Corporation common stock at the end of the three-year performance period. Each unit also earns the cash equivalent of the dividends paid during the performance period. Dividends accrued during the performance period are paid out only to the extent the performance measures are achieved and a payout under the program for that period occurs. The Long-Term Performance Unit Program is structured to reward Named Executive Officers only if performance goals set by the Personnel Committee are met. The Personnel Committee has no discretion to make awards if minimum performance goals are not achieved. Beginning with the 2012-2014 performance period, upon vesting, the performance units granted under the Long-Term Performance Unit Program will be settled in shares of Entergy Corporation common stock rather than cash. Accrued dividends on any shares earned under the plan will also be converted and paid in shares of Entergy Corporation common stock. Entergy modified the form of payment to align the method of payment with market practice and to encourage the executives to own shares of Entergy Corporation common stock. Executives are required to retain after-tax shares issued under the Long-Term Performance Unit Program until they have achieved their prescribed level of stock ownership under the stock ownership guidelines.

The Long-Term Performance Unit Program provides a minimum, target and maximum achievement level. Performance is measured by assessing Entergy Corporation's total shareholder return relative to the total shareholder return of the companies in the Philadelphia Utility Index. The Personnel Committee identified the Philadelphia Utility Index as the industry peer group for total shareholder return performance because the companies represented in this index closely approximate Entergy Corporation in terms of size and scale. The Personnel Committee chose total shareholder return as a measure of performance because it assesses Entergy Corporation's creation of shareholder value relative to other electric utilities over the performance period. It also takes into account dividends paid by the companies in this index and normalizes events that affect the industry as a whole. Minimum, target and maximum performance levels are determined by reference to the percentile ranking of Entergy Corporation's total shareholder return against the total shareholder return of the companies in the Philadelphia Utility Index. At any given time, a participant in the Long-Term Performance Unit Program may be participating in three performance periods. Currently participants are participating in the 2010-2012, the 2011-2013 and the 2012-2014 performance periods.

The 2011-2013 Performance Unit Program Grant. Subject to achievement of the performance levels, the Personnel Committee established target amounts of 26,000 performance units for Mr. Leonard; and 5,900 performance units for each of Mr. Denault and Mr. Taylor for the 2011-2013 performance period. The target amounts for the other Named Executive Officers are as follows: 2,500 performance units for Mr. Bunting and Mr. Mohl; 1,200 performance units for each of Mr. Domino, Mr. McDonald, Mr. Fisackerly and Mr. Rice. The range of payouts under the program is shown below.

Performance Levels:	Minimum	Target	Maximum
Total Shareholder Return	25th percentile	50th percentile	75th percentile
Payouts	25% of Target	100% of Target	200% of Target

There is no payout for performance below the 25th percentile. Payouts between minimum and target and target and maximum are calculated using straight line interpolation. Beginning with the 2011-2013 performance period, Entergy reduced the maximum payout under the Long-Term Performance Unit Program from 250% to 200% of target and increased the minimum payout from 10% to 25% of target to better align with market practice.

The Personnel Committee sets payout opportunities for the Long-Term Performance Unit Program at the outset of each performance period. In determining payout opportunities, the Committee considers several factors, including:

·	The advice of the Committee's independent compensation consultant regarding compensation practices at the industry peer group companies;

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·	Competitiveness of Entergy’s compensation plans and their ability to attract and retain top executive talent;

·	Target long-term compensation values in the market for similar jobs;

·	The desire to ensure, as described above, that a substantial portion of total compensation is performance-based;

·	The relative importance of the long-term performance goals established pursuant to the Performance Unit Program;

·	Internal pay equity and the executive pay structure;

·	The Committee’s assessment of other elements of compensation provided to the Named Executive Officers; and

·	Entergy’s Chief Executive Officer’s recommendation for the Named Executive Officers other than himself.

The Committee established a higher target amount for Mr. Leonard compared to the other Named Executive Officers based on the following factors:

·	Mr. Leonard's leadership and contributions to Entergy Corporation's success as measured by, among other things, the overall performance of Entergy Corporation.

·	Market practices that compensate chief executive officers at greater potential compensation levels with more "pay at risk" than other named executive officers.

Payout for the 2009-2011 Performance Period. For the 2009-2011 performance period, the target amounts were:

·	22,500 performance units for Mr. Leonard;

·	4,800 performance units for Mr. Denault and Mr. Taylor;

·	2,000 performance units for Mr. Bunting;

·	1,450 performance units for Mr. Mohl;

·	900 performance units each for Mr. Domino, Mr. Fisackerly and Mr. McDonald; and

·	450 performance units for Mr. Rice.

Participants could earn performance units based on relative total shareholder return and on the following range of payouts:

Performance Level	Minimum	Target	Maximum
Total Shareholder Return	25th percentile	50th percentile	75th percentile
Payouts	10% of target	100% of target	250% of Target

In January 2012, the Committee assessed Entergy Corporation’s total shareholder return for the 2009-2011 performance period in order to determine the actual number of performance units to be paid to Performance Unit Program participants for the 2009-2011 performance period. The Committee compared the Company's total shareholder return against the total shareholder return of the companies that comprise the Philadelphia Utility Index. Based on this comparison, the Committee concluded that Entergy Corporation’s performance for the 2009-2011 performance period, ranked in the bottom quartile. This resulted in no payout under the Performance Unit Program for the performance period.

·	Stock Options

The Personnel Committee and, in the case of the Named Executive Officers (other than Mr. Leonard, Mr. Denault and Mr. Taylor), Entergy’s Chief Executive Officer and the Named Executive Officer’s supervisor consider several factors in determining the amount of stock options it will grant to the Named Executive Officers, including:

·	Individual performance;

·	Prevailing market practice in stock option grants;

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·	The targeted long-term value created by the use of stock options;

·	Internal pay equity and the executive pay structure;

·	The number of participants eligible for stock options, and the resulting "burn rate" (i.e., the number of stock options authorized divided by the total number of shares outstanding) to assess the potential dilutive effect; and

·	The Committee's assessment of other elements of compensation provided to the Named Executive Officers based upon Entergy’s Chief Executive Officer’s recommendations for the Named Executive Officers other than himself.

For stock option awards to the Named Executive Officers (other than Mr. Leonard), the Committee's assessment of individual performance of each Named Executive Officer in consultation with Entergy Corporation's Chief Executive Officer, which involves a review of each officer’s performance, role and responsibilities, strengths and developmental opportunities and is the most important factor in determining the number of options awarded. The Committee also considers the significant achievements of Entergy for the prior year.

The following table sets forth the number of stock options granted to each Named Executive Officer in 2011. The exercise price for each option was $72.79, which was the closing price of Entergy Corporation common stock on the date of grant.

Named Executive Officer	Stock Options
J. Wayne Leonard	70,000
Leo P. Denault	25,000
Gary J. Taylor	20,000
Theodore H. Bunting, Jr.	6,800
Joseph F. Domino	2,900
Haley R. Fisackerly	2,900
Hugh T. McDonald	2,900
Willliam M. Mohl	6,100
Charles L. Rice	2,900

The option grants awarded to the Named Executive Officers (other than Mr. Leonard) ranged in number between 2,900 and 25,000 shares and were determined based on the factors described above. In the case of Mr. Leonard, who received 70,000 stock options, the Committee took special note of his performance as Entergy Corporation's Chief Executive Officer. The number of options granted to the Named Executive Officers decreased from prior year grants as a result of the addition of awards of restricted stock in 2011 as part of the executives’ long-term incentive compensation. Forty percent of the target value of the long-term incentive compensation for 2011 was allocated to the grant of stock options and restricted stock, equally divided in value, based on their grant date values. Entergy added restricted stock to the long-term compensation because Entergy believes it enhances retention, mitigates the burn rate and assists in building stock ownership.

For additional information regarding stock options awarded in 2011 to each of the Named Executive Officers, see the 2011 Grants of Plan-Based Awards table.

Under Entergy’s equity plans, all stock options must have an exercise price equal to the closing fair market value of Entergy Corporation common stock on the date of grant. In 2008, Entergy Corporation implemented guidelines that require an executive officer to achieve and maintain a level of Entergy Corporation stock ownership equal to a multiple of his or her salary. Until an executive officer satisfies the applicable stock ownership guidelines of Entergy Corporation common stock, the executive officer (including a Named Executive Officer) upon exercising any stock option granted on or after January 1, 2003, must retain at least 75% of the after-tax net profit from such stock option exercise in the form of Entergy Corporation common stock. The equity ownership plans prohibit the repricing of “underwater” stock options without shareholder approval.

Entergy Corporation has not adopted a formal policy regarding the granting of options at times when it is in possession of material non-public information. However, Entergy Corporation generally grants options to Named Executive Officers only during the month of January in connection with its annual executive compensation decisions. On occasion, it may grant options to newly hired employees or existing employees for retention or other limited purposes.

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·	Restricted Stock

During 2011, the Personnel Committee approved a change in the long-term incentive awards to include awards of restricted stock to the executive officers. The grant of restricted stock awards replaced a portion of the stock option awards historically granted to the executive officers. Entergy believes this change enhances retention, mitigates the burn rate and assists in building ownership of the common stock.

The restricted stock awards are intended to:

·	Align the interests of executive officers with the interests of shareholders by tying executive officers’ long-term financial interests to the long-term financial interests of shareholders;

·	Act as a retention mechanism for the key executives officers; and

·	Maintain a market competitive position for total compensation.

Shares of restricted stock vest over a three-year period, have voting rights and accrue dividends during the vesting period. Upon vesting, shares of Entergy common stock will be distributed along with the dividends that have accrued on the vested shares. Officers subject to the stock ownership guidelines will be required to retain vested shares until they satisfy the stock ownership guidelines.

The Personnel Committee considers several factors in determining the amount of restricted stock it will grant to the Named Executive Officers, including:

·	Individual performance;

·	Prevailing market practice in restricted stock grants;

·	The targeted long-term value created by the use of restricted stock;

·	Internal pay equity and the executive pay structure;

·	The number of participants eligible for restricted stock, and the resulting "burn rate" (i.e., the number of restricted shares authorized divided by the total number of shares outstanding) to assess the potential dilutive effect; and

·	The Committee's assessment of other elements of compensation provided to the Named Executive Officers based upon the Chief Executive Officer’s recommendations for the Named Executive Officers other than himself.

For restricted stock awards, the Committee's assessment of individual performance of each Named Executive Officer, in consultation with the Chief Executive Officer, involves a review of each officer’s performance, role and responsibilities, strengths and developmental opportunities is the most important factor in determining the number of shares of restricted stock awarded. The Committee also considers the significant achievements of Entergy for the prior year.

The following table sets forth the number of shares of restricted stock granted to each Named Executive Officer in 2011.

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Named Exeutive Officer	Shares of Restricted Stock
J. Wayne Leonard	11,500
Leo P. Denault	5,000
Gary J. Taylor	3,000
Theodore H. Bunting, Jr.	1,750
Joseph F. Domino	900
Haley R. Fisackerly	900
Hugh T. McDonald	900
William M. Mohl	1,100
Charles L. Rice	650

The shares of restricted stock awarded to the named executive officers (other than the Chief Executive Officer) ranged in number between 650 and 5,000 shares and were determined based on the factors described above. In the case of Entergy’s Chief Executive Officer, who received 11,500 shares of restricted stock in 2011, the Committee took special note of Mr. Leonard’s performance as Entergy Corporation’s Chief Executive Officer.

Benefits, Perquisites, Agreements and Post-Termination Plans

·	Pension Plan, Pension Equalization Plan and System Executive Retirement Plan

The Named Executive Officers are eligible to participate in the Pension Plan, Pension Equalization Plan and System Executive Retirement Plan. The Committee believes that these plans are an important part of the Named Executive Officers' compensation program. These plans are important in the recruitment of top talent in the competitive market, as these types of supplemental plans are typically found in companies of similar size to Entergy. These plans serve a critically important role in the retention of the senior executives, as benefits from these plans generally increase for each year that these executives remain employed by an Entergy system company. The plans thereby encourage the most senior executives to remain employed by Entergy and continue their work on behalf of Entergy’s shareholders.

The Named Executive Officers participate in an Entergy Corporation-sponsored pension plan that covers a broad group of employees. This pension plan is a funded, tax-qualified, noncontributory defined benefit pension plan. Benefits under the pension plan are based upon an employee's years of service with an Entergy system company and the employee's average monthly rate of “Eligible Earnings” (which generally includes the employee’s salary and eligible incentive awards, other than incentive awards paid under the Executive Incentive Plan) for the highest consecutive 60 months during the 120 months preceding termination of employment. Benefits under the tax-qualified plan are payable monthly after attainment of at least age 55 and after separation from an Entergy system company. The amount of annual earnings that may be considered in calculating benefits under the tax-qualified pension plan is limited by federal law.

Benefits under the tax-qualified pension plan in which the Named Executive Officer participates are calculated as an annuity payable at age 65 and equal to 1.5% of a participant's Eligible Earnings multiplied by years of service. Years of service under the pension plan formula cannot exceed 40. Contributions to the pension plan are made entirely by the employer and are paid into a trust fund from which the benefits of participants will be paid.

Entergy Corporation sponsors the Pension Equalization Plan, which is available to a select group of management and highly compensated employees, including the Named Executive Officers (other than Entergy’s Chief Executive Officer). The Pension Equalization Plan is a non-qualified unfunded supplemental retirement plan that provides for the payment to participants from an Entergy System employer's general assets a single lump sum cash distribution upon separation from service generally equal to the actuarial present value of the difference between the amount that would have been payable as an annuity under the tax-qualified pension plan, but for Internal Revenue Code limitations on pension benefits and earnings that may be considered in calculating tax-qualified pension benefits, and the amount actually payable as an annuity under the tax-qualified pension plan. The Pension Equalization Plan also takes into account as “Eligible Earnings” any incentive awards paid under the Executive Incentive Plan.

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Entergy Corporation also sponsors the System Executive Retirement Plan, which is available to Entergy’s approximately 60 officers, including the Named Executive Officers (other than Entergy’s Chief Executive Officer). Participation in the System Executive Retirement Plan requires individual approval by the plan administrator. An employee participating in both the System Executive Retirement Plan and the Pension Equalization Plan is eligible to receive only the greater of the two single-sum benefits computed in accordance with the terms and conditions of each plan.

Like the Pension Equalization Plan, the System Executive Retirement Plan is designed to provide for the payment to participants from an Entergy System employer’s general assets a single-sum cash distribution upon separation from service. The single-sum benefit is generally equal to the actuarial present value of a specified percentage of the participant’s “Final Average Monthly Compensation” (which is generally 1/36th of the sum of the participant's annual rate of base salary and Executive Incentive Plan award for the 3 highest years during the last 10 years preceding termination of employment), after first being reduced by the value of the participant’s tax-qualified Pension Plan benefit and typically any prior employer pension benefit available to the participant.

While the System Executive Retirement Plan has a replacement schedule from one year of service to the maximum of 30 years of service, the table below offers a sample ratio at 20 and 30 years of service.

Years of Service	Executives at Management Level 1	Executives at Management Level 3 and above	Executives at Management Level 4
20 years	55.0%	50.0%	45.0%
30 years	65.0%	60.0%	55.0%

Mr. Leonard's retention agreement (as further discussed below) provides that, in lieu of his participation in the Pension Equalization Plan and the System Executive Retirement Plan, upon the termination of his employment (unless such termination is for Cause, as defined in the agreement), he will be entitled to receive a benefit equal to 60% of his Final Average Compensation (as described in the description of the System Executive Retirement Plan above) calculated as a single life annuity and payable as an actuarial equivalent lump sum. This benefit will be reduced by other benefits to which he is entitled from any Entergy Corporation-sponsored pension plan or prior employer pension plans. The terms of Mr. Leonard's Supplemental Retirement Benefit were negotiated at the time his employment with Entergy Corporation commenced and were designed to, among other things, offset the loss of benefits resulting from Mr. Leonard's resignation from his prior employer. At the time that Entergy recruited Mr. Leonard, he had accumulated twenty-five years of seniority with his prior employer and had served as an executive officer for that employer for over ten years and in an officer-level capacity for over fifteen years.

The Entergy System company employer of Mr. Taylor and Mr. Denault has agreed to provide service credit to each of them under either the Pension Equalization Plan or the System Executive Retirement Plan. Entergy System company employers typically offer these service credit benefits as one element of the total compensation package offered to new mid-level or senior executives that are recruited from other companies. By offering these executives "credited service," Entergy Corporation is able to compete more effectively to hire these employees by mitigating the potential loss of their pension benefits resulting from accepting employment within the Entergy system.

See the 2011 Pension Benefits table for additional information regarding the operation of the plans described under this caption.

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·	Savings Plan

The Named Executive Officers are eligible to participate in an Entergy Corporation-sponsored Savings Plan that covers a broad group of employees. This is a tax-qualified retirement savings plan, wherein total combined before-tax and after-tax contributions may not exceed 30 percent of a participant's base salary up to certain contribution limits defined by law. In addition, under the Savings Plan, the participant's employer matches an amount equal to seventy cents for each dollar contributed by participating employees, including the Named Executive Officers, on the first six percent of their Earnings (as defined in the Savings Plan) for that pay period. Entergy Corporation maintains the Savings Plan for employees of participating Entergy System companies, including the Named Executive Officers, because it wishes to encourage employees to save some percentage of their cash compensation for their eventual retirement. The Savings Plan permits employees to make such savings in a manner that is relatively tax efficient. This type of savings plan is also a critical element in attracting and retaining talent in a competitive market.

·	Executive Deferred Compensation

The Named Executive Officers are eligible to defer up to 100% of their Executive Incentive Plan and Long-Term Performance Unit Program awards into either or both the Entergy-sponsored Executive Deferred Compensation Plan and the equity plan. In addition, they are eligible to defer up to 100% of their base salary into the Executive Deferred Compensation Plan.

Entergy provides these benefits because the Committee believes it is standard market practice to permit officers to defer the cash portion of their compensation. The Committee believes that providing this benefit is important as a retention and recruitment tool as many, if not all, of the companies with which they compete for executive talent provide a similar arrangement to the senior employees.

All deferral amounts represent an unfunded liability of the employer. Amounts deferred into the equity plan are deemed invested in phantom shares of Entergy Corporation common stock. Amounts deferred under the Executive Deferred Compensation Plan are deemed invested in one or more of the available investment options (generally mutual funds) offered under the Savings Plan.

Entergy does not "match" amounts that are deferred by employees pursuant to the Executive Deferred Compensation Plan or equity plan. With the exception of allowing for the deferral of federal and state taxes, no additional benefits are provided to the Named Executive Officer for deferring any of the above payments. Any increase in value of the deferred amounts results solely from the increase in value of the deemed investment options selected by the Named Executive Officer (phantom Entergy stock or mutual funds available under the Savings Plan).

Additionally, Mr. Leonard currently has a deferred account balance under a frozen Defined Contribution Restoration Plan. These amounts are deemed invested in the options available under this plan.

·	Health & Welfare Benefits

The Named Executive Officers are eligible to participate in various health and welfare benefits available to a broad group of employees. These benefits include medical, dental and vision coverage, life and accidental death and dismemberment insurance and long-term disability insurance. Eligibility, coverage levels, potential employee contributions and other plan design features are the same for the Named Executive Officers as for the broad employee population.

·	Executive Long-Term Disability Program

All executive officers, including the Named Executive Officers, are eligible to participate in the Entergy Corporation-sponsored Executive Long-Term Disability program. Individuals who elect to participate in this plan and become disabled under the terms of the plan are eligible for 65 percent of the difference between their base salary and $275,000 (i.e. the base salary that produces the maximum $15,000 monthly disability payment under the Entergy Corporation's general long-term disability plan).

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·	Perquisites

Entergy provides the Named Executive Officers with a limited number of perquisites and other personal benefits as part of providing a competitive executive compensation program and for employee retention. The Personnel Committee reviews all perquisites, including the use of corporate aircraft, on an annual basis. In 2011, the Named Executive Officers were offered the following personal benefits: corporate aircraft usage, relocation and housing benefits and annual mandatory physical exams. In 2011, Entergy discontinued providing personal financial counseling, club dues for members of the Office of Chief Executive and tax gross up payments on any perquisites, except for relocation benefits. The Named Executive Officers did not receive any additional compensation for the lost value of these discontinued perquisites.

For security and business reasons, Entergy permits its Chief Executive Officer to use its corporate aircraft at its expense for personal use. The other Named Executive Officers may use corporate aircraft for personal travel subject to the approval of Entergy Corporation's Chief Executive Officer. For additional information regarding perquisites, see the "All Other Compensation" column in the Summary Compensation Table.

·	Retention Agreements and other Compensation Arrangements

The Committee believes that retention and transitional compensation arrangements are an important part of overall compensation. The Committee believes that these arrangements help to secure the continued employment and dedication of the Named Executive Officers, notwithstanding any concern that they might have at the time of a change in control regarding their own continued employment. In addition, the Committee believes that these arrangements are important as recruitment and retention devices, as all or nearly all of the companies with which Entergy Corporation and the Subsidiaries compete for executive talent have similar arrangements in place for their senior employees.

To achieve these objectives, Entergy Corporation has established a System Executive Continuity Plan under which each of the Named Executive Officers (other than Entergy’s Chief Executive Officer and Chief Financial Officer) is entitled to receive "change in control" payments and benefits if such officer's employment is involuntarily terminated. Severance payments under the System Executive Continuity Plan are based on a multiple of the sum of an executive officer’s annual base salary plus his or her average Executive Incentive Plan award at target for the two fiscal years immediately preceding the fiscal year in which the termination of employment occurs. Under no circumstances can this multiple exceed 2.99 the sum of (a) annual base salary plus (b) the higher of: (i) the annual incentive award actually awarded to the executive office under the Executive Incentive Plan for the fiscal year immediately preceding the fiscal year in which the termination of employment occurs or (ii) the average Executive Incentive Plan award for the two fiscal years immediately preceding the fiscal year in which the termination of employment occurs. Entergy Corporation has strived to ensure that the benefits and payment levels under the System Executive Continuity Plan are consistent with market practices. The executive officers will not receive any tax gross up payments on any severance benefits received under this plan.

In certain cases, the Committee may approve the execution of a retention agreement with an individual executive officer. These decisions are made on a case by case basis to reflect specific retention needs or other factors, including market practice. If a retention agreement is entered into with an individual officer, the Committee considers the economic value associated with that agreement in making overall compensation decisions for the affected officer. Entergy Corporation has voluntarily adopted a policy that any severance arrangements providing benefits in excess of 2.99 times an officer's annual base salary and bonus must be approved by its shareholders.

At present, Entergy Corporation has entered into retention agreements with Mr. Leonard, Entergy’s Chief Executive Officer, and Mr. Denault, Entergy’s Chief Financial Officer. In general, these retention agreements provide for "change in control" payments and other benefits in lieu of those provided under the System Executive Continuity Plan. The retention agreements entered into with Mr. Leonard and Mr. Denault reflect, among other things, the competition for chief executive officer and chief financial officer talent in the market place and the Committee's assessment of the critical role of these officers in executing Entergy Corporation's long-term financial and other strategic objectives. Based on market data provided by its former independent compensation consultant, the Personnel Committee believes the benefits and payment levels under these retention agreements are consistent with market practices. As with any severance benefits paid under the System Executive continuity, and to align with best practices, in December 2011, both Mr. Leonard and Mr. Denault will not receive any tax gross up payments on any severance benefits they may receive under these agreements.

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For additional information regarding the System Executive Continuity Plan and the retention agreements described above, see "Potential Payments upon Termination or Change in Control."

Compensation Program Administration

Executive Compensation Governance

Entergy Corporation strives strive to ensure that the compensation philosophy and practices are in line with the best practices of companies in the industry as well as Fortune 500 companies. Some of these practices include the following:

Entergy’s ultimate objective is to deliver long-term value to shareholders as well as other stakeholders such as customers and employees. Entergy continually reviews and adjusts the pay programs so that the primary focus is on long-term success. Executives understand that successful long-term decision making will allow them to be paid their target compensation. Short term decisions that impair the long term value will reduce an executive’s compensation over the long term. To further this objective, beginning with the 2012-2014 performance period of the Long-Term Performance Unit Program, performance awards will be settled 100 percent in Entergy common stock upon vesting with all shares required to be retained until the officer satisfies their ownership requirements. In 2011, Entergy also increased the portion of long-term compensation that will be derived from performance units from 50% to 60% and decreased the portion that will be derived from other equity awards to 40%. Entergy added restricted stock awards to the long-term compensation program because it believes the use of restricted stock enhances retention, mitigates the burn rate and assists in building ownership of its common stock. Entergy believes that these actions further align the interest of the executive officers with those of the shareholders.

The adoption of the Entergy Corporation Policy Regarding Recoupment of Certain Compensation. This policy covers executive officers who are subject to Section 16 of the Exchange Act. Under the policy, the Committee will require reimbursement of incentives paid these executives where:

the payment was predicated upon the achievement of certain financial results with respect to the applicable performance period that were subsequently the subject of a material restatement other than a restatement due to changes in accounting policy or a material miscalculation of a performance award occurs whether or not the financial statements were restated;

·	in the Board of Directors’ view, the elected officer engaged in fraud that caused or partially caused the need for the restatement or caused a material miscalculation of a performance award whether or not the financial statements were restated; and

·	a lower payment would have been made to the elected officer based upon the restated financial results or miscalculation.

The amount the Committee requires to be reimbursed is equal to the excess of the gross incentive payment made over the gross payment that would have been made if the original payment had been determined based on the restated financial results or correct calculation. Further, following a material restatement of its financial statements, Entergy Corporation will seek to recover any compensation received by the Chief Executive Officer and Chief Financial Officer that is required to be reimbursed under Section 304 of the Sarbanes-Oxley Act of 2002

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Formalization of the timing and process for reviewing the executive compensation consultant services and fees. Annually, the Committee reviews the relationship with its compensation consultant including services provided, quality of those services and fees associated with services during the fiscal year to ensure executive compensation consultant independence is maintained. To ensure the independence of the Committee’s compensation consultant, Entergy’s Board adopted a policy that any consultant (including its affiliates) retained by the Board of Directors or any Committee of the Board of Directors to provide advice or recommendations on the amount or form of executive and director compensation should not be retained by Entergy Corporation or any of its affiliates to provide other services in an aggregate amount that exceeds $120,000. In 2011, Pay Governance did not provide any services to the Entergy other than its services to the Personnel Committee.

Adoption of an anti-hedging policy that prohibits officers, directors and employees from entering into hedging or monetization transactions involving Entergy Corporation common stock. Prohibited transactions include, without limitation, zero-cost collars, forward sale contracts, purchase or sale of options, puts, calls, straddles or equity swaps or other derivatives that are directly linked to the Entergy’s stock or transactions involving “short-sales” of Entergy’s stock. The Entergy Board adopted this policy to require officers, directors and employees to continue to own Entergy Corporation common stock with the full risks and rewards of ownership, thereby ensuring continued alignment of their objectives with Entergy’s other shareholders.

Reviewing the Executive Compensation Programs and Establishing Compensation Levels.

Role of Personnel Committee

The Personnel Committee has overall responsibility for approving the compensation program for the Named Executive Officers and makes all final compensation decisions regarding Entergy’s named executive officers. The Committee works with the executive management to ensure that the compensation policies and practices are consistent with Entergy’s values and support the successful recruitment, development and retention of executive talent so it can achieve the business objectives and optimize the long-term financial returns. The Committee evaluates executive pay each year to ensure that the compensation policies and practices are consistent with Entergy’s philosophy. The Personnel Committee is responsible for, among its other duties, the following actions related to Entergy Corporation's named executive officers:

·	developing and implementing compensation policies and programs for the executive officers, including any employment agreement with an executive officer;

·	evaluating the performance of Entergy Corporation's Chairman and Chief Executive Officer; and

·	reporting, at least annually, to the Board on succession planning, including succession planning for Entergy Corporation's Chief Executive Officer.

Certain aspects of the compensation of officers who are not Entergy Corporation named executive officers, Mr. Bunting, Mr. Domino, Mr. Fisackerly, Mr. McDonald, Mr. Mohl and Mr. Rice are not directly determined by the Personnel Committee. While the Committee does determine the number of performance units to be granted to these Named Executive Officers, the Committee does not determine the actual annual incentive target for these Named Executive Officers. Rather, the Committee establishes an overall available annual incentive pool for these officers and establishes the specific goal targets and ranges, the officers’ respective supervisor determines the actual incentive payment, in each case, subject to the ultimate approval of Entergy’s Chief Executive Officer. Further, Entergy’s Chief Executive Officer and the officer’s supervisor have ultimate responsibility for adjusting the salary of these Named Executive Officers as deemed appropriate. The officer’s supervisor and Entergy’s Chief Executive Officer also determine how many stock option and restricted stock awards are to be allocated to the Named Executive Officers from an available pool established by the Personnel Committee for similarly situated officers, though the Personnel Committee ultimately approves the options granted.

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Role of Chief Executive Officer

The Personnel Committee solicits recommendations from Mr. Leonard, Entergy Corporation's Chief Executive Officer, with respect to compensation decisions for Mr. Denault and Mr. Taylor. The Personnel Committee also relies on the recommendations of the senior human resources executives with respect to compensation decisions, policies and practices. Entergy’s Chief Executive Officer’s role is limited to:

·	providing the Committee with an assessment of the performance of Mr. Denault and Mr. Taylor; and

·	recommending base salary, annual merit increases, stock option, restricted stock and annual cash incentive plan compensation amounts for these officers.

In addition, the Committee may request that Mr. Leonard provide management feedback and recommendations on changes in the design of compensation programs, such as special retention plans or changes in the structure of bonus programs. Mr. Leonard does not play any role with respect to any matter affecting his own compensation nor does he have any role determining or recommending the amount, or form, of director compensation.

As noted above, under “Role of Personnel Committee,” Mr. Leonard also plays a role in determining the Subsidiary Named Executive Officers’ base salary, their annual incentive target and the number of stock options they receive.

Mr. Leonard may attend meetings of the Personnel Committee only at the invitation of the chair of the Personnel Committee and cannot call a meeting of the Committee. However, he is not in attendance at any meeting when the Committee determines and approves the compensation to be paid to the Named Executive Officers. Since he is not a member of the Committee, he has no vote on matters submitted to the Committee. During 2011, Mr. Leonard attended 5 meetings of the Personnel Committee.

Role of the Compensation Consultant

The Personnel Committee has the sole authority from the Entergy Board of Directors for the appointment, compensation and oversight of its outside compensation consultant. In 2011, the Personnel Committee retained Pay Governance LLC as its independent compensation consultant to assist it in, among other things, evaluating different compensation programs and developing market data to assess the compensation programs. Under the terms of its engagement, Pay Governance reports directly to the Personnel Committee, which has the right to retain or dismiss the consultant without the consent of Entergy’s management. Management may not retain Pay Governance for any services that in an aggregate amount would exceed $120,000.

During 2011, Pay Governance assisted the Committee with its responsibilities related to Entergy’s compensation programs for its executives. Specifically, the Committee directed Pay Governance to: (i) regularly attend meetings of the Committee, (ii) conduct studies of competitive compensation practices, (iii) identify Entergy’s market surveys and proxy peer group, (iv) review base salary, annual incentives and long-term incentive compensation opportunities relative to competitive practices, and (v) develop conclusions and recommendations related to the executive compensation plan of Entergy for consideration by the Committee. A senior consultant from Pay Governance attended all Personnel Committee meetings in 2011. Pay Governance did not provide any other services to Entergy in 2011.

Tax and Accounting Considerations

Section 162(m) of the Internal Revenue Code limits the tax deductibility by a publicly held corporation of compensation in excess of $1 million paid to a Chief Executive Officer or any of its other Named Executive Officers (other than the chief financial officer), unless that compensation is "performance-based compensation" within the meaning of Section 162(m). The Personnel Committee considers deductibility under Section 162(m) as it structures the

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compensation packages that are provided to Entergy’s Named Executive Officers. However, the Personnel Committee and the Board believe that it is in the best interest of Entergy Corporation that the Personnel Committee retains the flexibility and discretion to make compensation awards, whether or not deductible. This flexibility is necessary to foster achievement of performance goals established by the Personnel Committee as well as other corporate goals that the Committee deems important to Entergy Corporation and the Subsidiaries' success, such as encouraging employee retention and rewarding achievement.

Likewise, the Personnel Committee considers financial accounting consequences as it structures the compensation packages that are provided to Entergy’s Named Executive Officers. However, the Personnel Committee and the Entergy Board of Directors believe that it is in the best interest of Entergy that the Personnel Committee retains the flexibility and discretion to make compensation awards regardless of their financial accounting consequences.

PERSONNEL COMMITTEE REPORT

The "Personnel Committee Report" included in the Entergy Corporation Proxy Statement is incorporated by reference, but will not be deemed to be "filed" in this Annual Report on Form 10-K. None of the Subsidiaries has a compensation committee, or other board committee performing equivalent functions. The board of directors of each of the Subsidiaries is comprised of individuals who are officers or employees of Entergy Corporation or one of the Subsidiaries. These boards do not make determinations regarding the compensation paid to executive officers of the Subsidiaries.

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EXECUTIVE COMPENSATION TABLES

2011 Summary Compensation Table

The following table summarizes the total compensation paid or earned by each of the Named Executive Officers for the fiscal years ended December 31, 2011, 2010 and 2009. For information on the principal positions held by each of the Named Executive Officers, see Item 10, “Directors and Executive Officers of the Registrants.” The compensation set forth in the table represents the aggregate compensation paid by all Entergy System companies. None of the Entergy System companies has entered into any employment agreements with any of the Named Executive Officers (other than the retention agreements described in “Potential Payments upon Termination or Change in Control”). For additional information regarding the material terms of the awards reported in the following tables, including a general description of the formula or criteria to be applied in determining the amounts payable, see “Compensation Discussion and Analysis.”

(a)	(b)	(c)	(d)	(e)	(f)	(g)	(h)	(i)	(j)
Name and Principal Position	Year	Salary (1)	Bonus (2)	Stock Awards (3)	Option Awards (4)	Non-Equity Incentive Plan Compensation (5)	Change in Pension Value and Non-qualified Deferred Compensation Earnings (6)	All Other Compensation (7)	Total

Theodore H. Bunting, Jr.	2011	$356,884	$ -	$351,108	$78,064	$400,000	$632,100	$14,094	$1,832,250
Acting principal financial	2010	$350,448	$ -	$237,864	$194,155	$525,000	$392,300	$22,609	$1,722,376
officer – Entergy Arkansas,	2009	$361,388	$ -	$174,380	$143,280	$335,000	$535,700	$23,065	$1,572,813
Entergy Gulf States Louisiana,
Entergy Louisiana, Entergy
Mississippi, Entergy New
Orleans, Entergy Texas

Leo P. Denault	2011	$648,512	$ -	$891,941	$287,000	$587,059	$980,400	$16,756	$3,411,668
Executive Vice President and	2010	$630,000	$ -	$573,036	$669,500	$758,520	$528,600	$52,276	$3,211,932
CFO – Entergy Corp.	2009	$654,231	$ -	$418,512	$537,300	$507,150	$837,200	$60,688	$3,015,081

Joseph F. Domino	2011	$322,418	$ -	$172,899	$33,292	$215,000	$573,500	$19,207	$1,336,316
CEO - Entergy Texas	2010	$317,754	$ -	$108,120	$61,594	$317,754	$224,500	$33,476	$1,063,198
	2009	$329,976	$10,000	$78,471	$53,730	$111,373	$322,100	$45,396	$951,046

Haley R. Fisackerly	2011	$280,885	$ -	$172,899	$33,292	$150,000	$295,700	$16,603	$949,379
CEO – Entergy Mississippi	2010	$274,999	$ -	$108,120	$120,510	$192,500	$190,000	$39,370	$925,499
	2009	$274,999	$8,250	$78,471	$45,372	$138,000	$168,300	$35,675	$749,067

J. Wayne Leonard	2011	$1,315,229	$ -	$3,163,825	$803,600	$2,033,356	$2,749,700	$65,061	$10,130,771
Chairman of the Board and	2010	$1,291,500	$ -	$2,411,076	$1,807,650	$2,665,656	$ -	$104,185	$8,280,067
CEO - Entergy Corp.	2009	$1,341,174	$ -	$10,067,775	$1,492,500	$1,782,270	$499,800	$200,040	$15,383,559

Hugh T. McDonald	2011	$327,892	$ -	$172,899	$33,292	$210,000	$485,000	$28,320	$1,257,403
CEO-Entergy Arkansas	2010	$322,132	$ -	$108,120	$61,594	$297,972	$205,000	$54,990	$1,049,808
	2009	$324,610	$10,000	$78,471	$53,730	$128,066	$252,500	$67,221	$914,598

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(a)	(b)	(c)	(d)	(e)	(f)	(g)	(h)	(i)	(j)
Name and Principal Position	Year	Salary (1)	Bonus (2)	Stock Awards (3)	Option Awards (4)	Non-Equity Incentive Plan Compensation (5)	Change in Pension Value and Non-qualified Deferred Compensation Earnings (6)	All Other Compensation (7)	Total

William M. Mohl	2011	$332,751	$ -	$303,794	$70,028	$265,000	$388,900	$26,668	$1,387,141
CEO-Entergy Louisiana and	2010	$299,193	$ -	$216,240	$120,510	$380,250	$166,718	$148,767	$1,331,678
CEO-Entergy Gulf States
Louisiana

Charles L. Rice, Jr.	2011	$245,312	$ -	$154,702	$33,292	$130,000	$78,400	$20,594	$662,300
CEO-Entergy New Orleans	2010	$203,879	$9,962	$90,064	$ -	$192,000	$30,944	$18,708	$545,557

Gary J. Taylor	2011	$586,750	$171,000	$746,361	$229,600	$531,148	$854,500	$24,209	$3,143,568
Group President,	2010	$570,000	$171,000	$573,036	$535,600	$686,280	$438,800	$92,680	$3,067,396
Utility Operations	2009	$591,924	$105,000	$418,512	$358,200	$458,850	$706,600	$87,946	$2,727,032
Entergy Corp.

(1)	The amounts in column (c) represent the actual base salary paid to the Named Executive Officer. The 2011 changes in base salaries were effective in April 2011. The Named Executive Officers are paid on a bi-weekly basis and during 2009 there was an extra pay period.
(2)	The amounts in column (d) for Mr. Taylor represent the cash bonus paid to him pursuant to the Nuclear Retention Plan. See “Non-Equity Incentive Plans – Nuclear Retention Plan” in Compensation Discussion and Analysis.
(3)	The amounts in column (e) represent the aggregate grant date fair value of restricted stock and performance units granted under the 2007 Equity Ownership Plan calculated in accordance with FASB ASC Topic 718, without taking into account estimated forfeitures. The grant date fair value of the restricted stock is based on the closing price of Entergy Corporation common stock on the date of grant. The grant date fair value of performance units is based on the probable outcome of the applicable performance conditions, measured using a Monte Carlo simulation valuation model. The simulation model applies a risk-free interest rate and an expected volatility assumption. The risk-free rate is assumed to equal the yield on a three-year treasury bond on the grant date. Volatility is based on historical volatility for the 36-month period preceding the grant date. If the highest achievement level is attained, the maximum amounts that will be received with respect to the 2011 performance units are as follows: Mr. Bunting, $363,950; Mr. Denault, $858,922; Mr. Domino, $174,696; Mr. Fisackerly, $174,696; Mr. Leonard, $3,785,080; Mr. McDonald, $174,696; Mr. Mohl, $363,950; Mr. Rice, $174,696; and Mr. Taylor, $858,922.
(4)	The amounts in column (f) represent the aggregate grant date fair value of stock options granted under the 2007 Equity Ownership Plan calculated in accordance with FASB ASC Topic 718. For a discussion of the relevant assumptions used in valuing these awards, see Note 12 to the Financial Statements.
(5)	The amounts in column (g) represent cash payments made under the Executive Incentive Plan.
(6)	The amounts in column (h) include the annual actuarial increase in the present value of the Named Executive Officer’s benefits under all pension plans established by Entergy Corporation using interest rate and mortality rate assumptions consistent with those used in Entergy Corporation’s financial statements and includes amounts which the Named Executive Officers may not currently be entitled to receive because such amounts are not vested (see “2010 Pension Benefits”). None of the increase is attributable to above-market or preferential earnings on non-qualified deferred compensation (see “2011 Non-qualified Deferred Compensation”). For 2010 the aggregate change in the actuarial present value of Mr. Leonard’s pension benefits was a decrease of $539,200.
(7)	The amounts set forth in column (i) for 2011 include (a) matching contributions by Entergy Corporation to each of the Named Executive Officers; (b) life insurance premiums; (c) tax gross up payments relating to relocation benefits; and (d) perquisites and other compensation. The amounts are listed in the following table:

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Named Executive Officer	Company Contribution – Savings Plan	Life Insurance Premium	Tax Gross Up Payments	Perquisites and Other Compensation	Total
Theodore H. Bunting, Jr.	$10,290	$3,804	$ -	$ -	$14,094
Leo P. Denault	$10,290	$4,002	$ -	$2,464	$16,756
Joseph F. Domino	$10,290	$5,995	$ -	$2,922	$19,207
Haley R. Fisackerly	$9,338	$417	$ -	$6,848	$16,603
J. Wayne Leonard	$10,290	$11,484	$ -	$43,287	$65,061
Hugh T. McDonald	$10,290	$3,486	$ -	$14,544	$28,320
William M. Mohl	$10,290	$3,539	$3,770	$9,069	$26,668
Charles L. Rice, Jr.	$10,290	$3,168	$ -	$7,136	$20,594
Gary J. Taylor	$10,290	$7,316	$ -	$6,603	$24,209

Effective January 2011, Entergy Corporation eliminated tax gross up payments on all perquisites, except for relocation benefits.

Perquisites and Other Compensation

The amounts set forth in column (i) include perquisites and other personal benefits that Entergy Corporation provides to the Named Executive Officers as part of providing a competitive executive compensation program and for employee retention. Beginning in January 2011, Entergy Corporation discontinued providing personal financial counseling and club dues for members of the Office of Chief Executive and in 2011, the Named Executive Officers were offered the following personal benefits: corporate aircraft usage, relocation and housing benefits and annual mandatory physical exams. The following perquisites and other compensation were provided by Entergy Corporation in 2011 with the financial counseling and club dues reflecting perquisites received in 2010, but paid in 2011.

Named Executive Officer	Financial Counseling	Club Dues	Personal Use of Corporate Aircraft	Relocation	Executive Physicals
Theodore H. Bunting, Jr.
Leo P. Denault	x				x
Joseph F. Domino	x				x
Haley R. Fisackerly	x	x
J. Wayne Leonard	x		x		x
Hugh T. McDonald	x	x
William M. Mohl	x	x		x
Charles L. Rice, Jr.		x			x
Gary J. Taylor	x	x	x		x

For security and business reasons, Entergy Corporation permits Mr. Leonard to use its corporate aircraft for personal use at the expense of Entergy Corporation. The other Named Executive Officers may use the corporate aircraft for personal travel subject to the approval of Entergy Corporation’s Chief Executive Officer. The aggregate incremental aircraft usage cost associated with Mr. Leonard’s personal use of the corporate aircraft, including the costs associated with travel to outside board meetings, was $36,823 for fiscal year 2011. These amounts are reflected in column (i) and the total above. The incremental cost to Entergy Corporation for use of the corporate aircraft is based on the variable operational costs of each flight, including fuel, maintenance, flight crew travel expense, catering, communications and fees, including flight planning, ground handling and landing permits.

None of the other perquisites referenced above exceeded $25,000 for any of the other Named Executive Officers.

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2011 Grants of Plan-Based Awards

The following table summarizes award grants during 2011 to the Named Executive Officers.

		Estimated Future Payouts Under Non-Equity Incentive Plan Awards(1)			Estimated Future Payouts under Equity Incentive Plan Awards(2)
(a) Name	(b) Grant Date	(c) Thresh- old ($)	(d) Target ($)	(e) Maximum ($)	(f) Threshold (#)	(g) Target (#)	(h) Maximum (#)	(i) All Other Stock Awards: Number of Shares of Stock or Units (#) (3)	(j) All Other Option Awards: Number of Securities Under- lying Options (#) (4)	(k) Exercise or Base Price of Option Awards ($/Sh)	(l) Grant Date Fair Value of Stock and Option Awards (5)

Theodore H. Bunting, Jr.	1/27/11	-	$215,525	$431,050
	1/27/11				625	2,500	5,000				$223,725
	1/27/11							1,750			$127,383
	1/27/11								6,800	$72.79	$78,064

Leo P. Denault	1/27/11	-	$458,640	$917,280
	1/27/11				1,475	5,900	11,800				$527,991
	1/27/11							5,000			$363,950
	1/27/11								25,000	$72.79	$287,000

Joseph F. Domino	1/27/11	-	$162,052	$324,104
	1/27/11				300	1,200	2,400				$107,388
	1/27/11							900			$65,511
	1/27/11								2,900	$72.79	$33,292

Haley R. Fisackerly	1/27/11	-	$113,300	$226,600
	1/27/11				300	1,200	2,400				$107,388
	1/27/11							900			$65,511
	1/27/11								2,900	$72.79	$33,292

J. Wayne Leonard	1/27/11	-	$1,588,560	$3,177,120
	1/27/11				6,500	26,000	52,000				$2,326,740
	1/27/11							11,500			$837,085
	1/27/11								70,000	$72.79	$803,600

Hugh T. McDonald	1/27/11	-	$161,000	$322,000
	1/27/11				300	1,200	2,400				$107,388
	1/27/11							900			$65,511
	1/27/11								2,900	$72.79	$33,292

William M. Mohl	1/27/11	-	$201,330	$402,660
	1/27/11				625	2,500	5,000				$223,725
	1/27/11							1,100			$80,069
	1/27/11								6,100	$72.79	$70,028

Charles L. Rice, Jr.	1/27/11	-	$98,880	$197,760
	1/27/11				300	1,200	2,400				$107,388
	1/27/11							650			$47,314
	1/27/11								2,900	$72.79	$33,292

Gary J. Taylor	1/27/11	-	$414,960	$829,920
	1/27/11				1,475	5,900	11,800				$527,991
	1/27/11							3,000			$218,370
	1/27/11								20,000	$72.79	$229,600

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(1)	The amounts in columns (c), (d) and (e) represent minimum, target and maximum payment levels under the Annual Incentive Plan. The actual amounts awarded are reported in column (g) of the Summary Compensation Table.
(2)	The amounts in columns (f), (g) and (h) represent the minimum, target and maximum payment levels under the Performance Unit Program. Performance under the program is measured by Entergy Corporation’s total shareholder return relative to the total shareholder returns of the companies included in the Philadelphia Utility Index. If Entergy Corporation’s total shareholder return is not at least 25% of that for the Philadelphia Utility Index, there is no payout. Subject to achievement of performance targets, each unit will be converted into the cash equivalent of one share of Entergy Corporation’s common stock on the last day of the performance period (December 31, 2013.)
(3)	The amounts in column (i) represent shares of restricted stock granted under the 2007 Equity Ownership Plan. Shares of restricted stock vest over a three-year period, have voting rights and accrue dividends during the vesting period.
(4)	The amounts in column (j) represent options to purchase shares of Entergy Corporation’s common stock. The options vest one-third on each of the first through third anniversaries of the grant date and have a ten-year term from the date of grant. The options were granted under the 2007 Equity Ownership Plan.
(5)	The amounts in column (l) are valued based on the aggregate grant date fair value of the award calculated in accordance with FASB ASC Topic 718 and, in the case of the performance units, are based on the probable outcome of the applicable performance conditions. See Notes 2 and 3 to the Summary Compensation Table for a discussion of the relevant assumptions used in calculating the grant date fair value.

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2011 Outstanding Equity Awards at Fiscal Year-End

The following table summarizes unexercised options, stock that has not vested and equity incentive plan awards for each Named Executive Officer outstanding as of the end of 2011.

	Option Awards					Stock Awards
(a) Name	(b) Number of Securities Underlying Unexercised Options (#) Exercisable	(c) Number of Securities Underlying Unexercised Options (#) Unexercisable	(d) Equity Incentive Plan Awards: Number of Securities Underlying Unexercised Unearned Options (#)	(e) Option Exercise Price ($)	(f) Option Expiration Date	(g) Number of Shares or Units of Stock That Have Not Vested (#)	(h) Market Value of Shares or Units of Stock That Have Not Vested ($)	(i) Equity Incentive Plan Awards: Number of Unearned Shares, Units or Other Rights That Have Not Vested (#)	(j) Equity Incentive Plan Awards: Market or Payout Value of Unearned Shares, Units or Other Rights That Have Not Vested ($)

Theodore H.	-	6,800(1)		$72.79	1/27/2021
Bunting, Jr.	4,833	9,667(2)		$77.10	1/28/2020
	8,000	4,000(3)		$77.53	1/29/2019
	18,000	-		$108.20	1/24/2018
	10,000	-		$91.82	1/25/2017
	5,000	-		$68.89	1/26/2016
	2,200	-		$69.47	1/27/2015
	1,000	-		$58.60	3/02/2014
								625(4)	$45,656
								220(5)	$16,071
						1,750(6)	$127,838

Leo P. Denault	-	25,000(1)		$72.79	1/27/2021
	16,666	33,334(2)		$77.10	1/28/2020
	30,000	15,000(3)		$77.53	1/29/2019
	50,000	-		$108.20	1/24/2018
	60,000	-		$91.82	1/25/2017
	50,000	-		$68.89	1/26/2016
	35,000	-		$69.47	1/27/2015
	34,995	-		$58.60	3/02/2014
	338	-		$52.40	2/11/2012
	6,802	-		$44.45	1/30/2013
	10,493	-		$41.69	2/11/2012
								1,475(4)	$107,749
								530(5)	$38,717
						5,000(6)	$365,250
						16,000(7)	$1,168,800

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	Option Awards					Stock Awards
(a) Name	(b) Number of Securities Underlying Unexercised Options (#) Exercisable	(c) Number of Securities Underlying Unexercised Options (#) Unexercisable	(d) Equity Incentive Plan Awards: Number of Securities Underlying Unexercised Unearned Options (#)	(e) Option Exercise Price ($)	(f) Option Expiration Date	(g) Number of Shares or Units of Stock That Have Not Vested (#)	(h) Market Value of Shares or Units of Stock That Have Not Vested ($)	(i) Equity Incentive Plan Awards: Number of Unearned Shares, Units or Other Rights That Have Not Vested (#)	(j) Equity Incentive Plan Awards: Market or Payout Value of Unearned Shares, Units or Other Rights That Have Not Vested ($)
Joseph F. Domino	-	2,900(1)		$72.79	1/27/2021
	1,533	3,067(2)		$77.10	1/28/2020
	3,000	1,500(3)		$77.53	1/29/2019
	7,000	-		$108.20	1/24/2018
	12,000	-		$91.82	1/25/2017
	7,500	-		$68.89	1/26/2016
	10,000	-		$69.47	1/27/2015
	10,000	-		$58.60	3/02/2014
	10,500	-		$44.45	1/30/2013
								300(4)	$21,915
								100(5)	$7,305
						900(6)	$65,745

Haley R. Fisackerly	-	2,900(1)		$72.79	1/27/2021
	3,000	6,000(2)		$77.10	1/28/2020
	2,533	1,267(3)		$77.53	1/29/2019
	5,000	-		$108.20	1/24/2018
	2,500	-		$91.82	1/25/2017
	1,000	-		$68.89	1/26/2016
								300(4)	$21,915
								100(5)	$7,305
						900(6)	$65,745

J. Wayne Leonard	-	70,000(1)		$72.79	1/27/2021
	45,000	90,000(2)		$77.10	1/28/2020
	83,333	41,667(3)		$77.53	1/29/2019
	175,000	-		$108.20	1/24/2018
	255,000	-		$91.82	1/25/2017
	210,000	-		$68.89	1/26/2016
	165,200	-		$69.47	1/27/2015
	220,000	-		$58.60	3/02/2014
	195,000	-		$44.45	1/30/2013
								6,500(4)	$474,825
								2,230(5)	$162,902
						11,500(6)	$840,075
						50,000(8)	$3,652,500

Hugh T. McDonald	-	2,900(1)		$72.79	1/27/2021
	1,533	3,067(2)		$77.10	1/28/2020
	3,000	1,500(3)		$77.53	1/29/2019
	7,000	-		$108.20	1/24/2018
	12,000	-		$91.82	1/25/2017
	7,500	-		$68.89	1/26/2016
	12,522	-		$73.25	2/11/2012
	10,000	-		$69.47	1/27/2015
	10,000	-		$58.60	3/02/2014
								300(4)	$21,915
								100(5)	$7,305
						900(6)	$65,745

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	Option Awards					Stock Awards
(a) Name	(b) Number of Securities Underlying Unexercised Options (#) Exercisable	(c) Number of Securities Underlying Unexercised Options (#) Unexercisable	(d) Equity Incentive Plan Awards: Number of Securities Underlying Unexercised Unearned Options (#)	(e) Option Exercise Price ($)	(f) Option Expiration Date	(g) Number of Shares or Units of Stock That Have Not Vested (#)	(h) Market Value of Shares or Units of Stock That Have Not Vested ($)	(i) Equity Incentive Plan Awards: Number of Unearned Shares, Units or Other Rights That Have Not Vested (#)	(j) Equity Incentive Plan Awards: Market or Payout Value of Unearned Shares, Units or Other Rights That Have Not Vested ($)

William M. Mohl	-	6,100(1)		$72.79	1/27/2021
	3,000	6,000(2)		$77.10	1/28/2020
	5,000	2,500(3)		$77.53	1/29/2019
	9,300	-		$108.20	1/24/2018
	3,500	-		$91.82	1/25/2017
	5,000	-		$68.89	1/26/2016
	3,000	-		$69.47	1/27/2015
								625(4)	$45,656
								200(5)	$14,610
						1,100(6)	$80,355

Charles L. Rice, Jr.	-	2,900(1)		$72.79	1/27/2021
								300(4)	$21,915
								83(5)	$6,063
						650(6)	$47,483

Gary J. Taylor	-	20,000(1)		$72.79	1/27/2021
	13,333	26,667(2)		$77.10	1/28/2020
	20,000	10,000(3)		$77.53	1/29/2019
	35,000	-		$108.20	1/24/2018
	60,000	-		$91.82	1/25/2017
	50,000	-		$68.89	1/26/2016
	35,000	-		$69.47	1/27/2015
	40,000	-		$58.60	3/02/2014
	26,900	-		$44.45	1/30/2013
								1,475(4)	$107,749
								530(5)	$38,717
						3,000(6)	$219,150

(1)	Consists of options that vested or will vest as follows: 1/3 of the options granted vest on each of 1/27/2012, 1/27/2013 and 1/27/2014.
(2)	Consists of options that vested or will vest as follows: 1/2 of the remaining unexercisable options vest on each of 1/28/2012 and 1/28/2013.
(3)	The remaining unexercisable options vested on 1/29/2012.
(4)	Consists of performance units that will vest on December 31, 2013 based on Entergy Corporation’s total shareholder return performance over the 2011 – 2013 performance period as described under “Long-Term Compensation – Performance Unit Program” in Compensation Discussion and Analysis.
(5)	Consists of performance units that will vest on December 31, 2012 based on Entergy Corporation’s total shareholder return performance over the 2010 – 2012 performance period.
(6)	Consists of shares of restricted stock granted under the 2007 Equity Ownership Plan that vested or will vest as follows: 1/3 of the shares of restricted stock granted vest on each of 1/27/2012, 1/27/2013 and 1/27/2014.
(7)	Consists of restricted units granted under the 2007 Equity Ownership Plan. 8,000 units vested on January 25, 2012 and an additional 8,000 will vest on January 25, 2013.
(8)	Consists of restricted units granted under the 2007 Equity Ownership Plan which will vest on December 3, 2012.

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2011 Option Exercises and Stock Vested

The following table provides information concerning each exercise of stock options and each vesting of stock during 2011 for the Named Executive Officers.

	Options Awards		Stock Awards
(a) Name	(b) Number of Shares Acquired on Exercise (#)	(c) Value Realized on Exercise ($)	(d) Number of Shares Acquired on Vesting (#)	(e) Value Realized on Vesting ($)

Theodore H. Bunting, Jr.	-	$ -	-	$ -

Leo P. Denault	-	$ -	8,000(1)	$588,000

Joseph F. Domino	-	$ -	-	$ -

Haley R. Fisackerly	-	$ -	-	$ -

J. Wayne Leonard	330,600	$8,218,518	50,000(2)	$3,482,000

Hugh T. McDonald	12,000	$292,748	-	$ -

William M. Mohl	-	$ -	-	$ -

Charles L. Rice, Jr.	-	$ -	-	$ -

Gary J. Taylor	34,600	$867,087	-	$ -

(1)	Represents the January 25, 2011 cash settlement of 8,000 restricted units granted under the 2007 Equity Ownership Plan.
(2)	Represents the December 3, 2011 cash settlement of 50,000 restricted units granted under the 2007 Equity Ownership Plan.

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2011 Pension Benefits

The following table shows the present value as of December 31, 2011, of accumulated benefits payable to each of the Named Executive Officers, including the number of years of service credited to each Named Executive Officer, under the retirement plans sponsored by Entergy Corporation, determined using interest rate and mortality rate assumptions set forth in Note 11 to the Financial Statements. Information regarding these retirement plans is included in Compensation Discussion & Analysis under the heading, “Benefits, Perquisites, Agreements and Post-Retirement Plans - Pension Plan, Pension Equalization Plan, and System Executive Retirement Plan.” In addition, this section includes information regarding early retirement options under the plans.

Name	Plan Name	Number of Years Credited Service	Present Value of Accumulated Benefit	Payments During 2011
Theodore H. Bunting, Jr.	Non-qualified System Executive Retirement Plan	23.86	$2,256,400	$ -
	Qualified defined benefit plan	23.86	$567,800	$ -

Leo P. Denault (1)	Non-qualified System Executive Retirement Plan	27.83	$4,611,200	$ -
	Qualified defined benefit plan	12.83	$293,000	$ -

Joseph F. Domino (2)	Non-qualified System Executive Retirement Plan	41.56	$1,947,900	$ -
	Qualified defined benefit plan	38.13	$1,462,700	$ -

Haley R. Fisackerly	Non-qualified System Executive Retirement Plan	16.08	$631,400	$ -
	Qualified defined benefit plan	16.08	$288,000	$ -

J. Wayne Leonard (3)	Non-qualified supplemental retirement plan benefit	13.68	$26,343,300	$ -
	Qualified defined benefit plan	13.68	$477,000	$ -

Hugh T. McDonald (2)	Non-qualified System Executive Retirement Plan	29.93	$1,328,800	$ -
	Qualified defined benefit plan	28.44	$691,300	$ -

William M. Mohl	Non-qualified System Executive Retirement Plan	9.44	$755,400	$ -
	Qualified defined benefit plan	9.44	$217,200	$ -

Charles L. Rice, Jr.	Non-qualified System Executive Retirement Plan	2.47	$69,300	$ -
	Qualified defined benefit plan	2.47	$43,800	$ -

Gary J. Taylor (4)	Non-qualified System Executive Retirement Plan	21.80	$4,556,500	$ -
	Qualified defined benefit plan	11.80	$364,600	$ -

(1)	During 2006, Mr. Denault entered into an agreement granting an additional 15 years of service under the non-qualified System Executive Retirement Plan if he continues to work for an Entergy System company employer until age 55. The additional 15 years of service increases the present value of his benefit by $1,641,200.
(2)	Service under the non-qualified System Executive Retirement Plan is granted from date of hire. Qualified plan benefit service is granted from the later of date of hire or plan participation date.

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(3)

Pursuant to his retention agreement, Mr. Leonard is entitled to a non-qualified supplemental retirement benefit in lieu of participation in Entergy Corporation’s non-qualified supplemental retirement plans such as the System Executive Retirement Plan or the Pension Equalization Plan. Mr. Leonard may separate from employment without a reduction in his non-qualified supplemental retirement benefit.

(4)

Mr. Taylor entered into an agreement granting an additional 10 years of service under the System Executive Retirement Plan resulting in a $1,306,200 increase in the present value of his benefit. Mr. Taylor has advised Entergy Corporation that he intends to resign from his position as Group President, Utility Operations, effective May 31, 2012.

Qualified Retirement Benefits

The qualified retirement plan is a funded defined benefit pension plan that provides benefits to most of the non-bargaining unit employees of Entergy System companies. All Named Executive Officers are participants in this plan. The pension plan provides a monthly benefit payable for the participant’s lifetime beginning at age 65 and equal to 1.5% of the participant’s five-year final average monthly eligible earnings times such participant’s years of service. Participants are 100% vested in their benefit upon completing 5 years of vesting service.

Normal retirement under the plan is age 65. Employees who terminate employment prior to age 55 may receive a reduced deferred vested retirement benefit payable as early as age 55 that is actuarially equivalent to the normal retirement benefit (i.e., reduced by 7% per year for the first 5 years preceding age 65, and reduced by 6% for each additional year thereafter). Employees who are at least age 55 with 10 years of vesting service upon termination from employment are entitled to a subsidized early retirement benefit beginning as early as age 55. The subsidized early retirement benefit is equal to the normal retirement benefit reduced by 2% per year for each year that early retirement precedes age 65.

Mr. Domino, Mr. Leonard and Mr. Taylor are eligible for subsidized early retirement benefits.

Non-qualified Retirement Benefits

The Named Executive Officers are eligible to participate in certain non-qualified retirement benefit plans that provide retirement income, including the Pension Equalization Plan and the System Executive Retirement Plan. Each of these plans is an unfunded non-qualified defined benefit pension plan that provides benefits to key management employees. In these plans, each described below and in Compensation Discussion and Analysis, an executive is typically enrolled in one or more plans but only paid the amount due under the plan that provides the highest benefit. In general, upon disability, participants in the Pension Equalization Plan and the System Executive Retirement Plan remain eligible for continued service credits until recovery or retirement. Generally, spouses of participants who die before commencement of benefits may be eligible for a portion of the participant’s accrued benefit.

The Pension Equalization Plan

All of the Named Executive Officers (with the exception of Mr. Leonard) are participants in the Pension Equalization Plan. The benefit provisions are substantially the same as the qualified retirement plan but provide two additional benefits: (a) “restorative benefits” intended to offset limitations on certain earnings that may be considered in connection with the qualified retirement plan and (b) supplemental credited service (if granted to an individual participant). The benefits under this plan are offset by benefits payable from the qualified retirement plan and may be offset by prior employer benefits. Participants receive their Pension Equalization Plan benefit in the form of a single sum cash distribution. The Pension Equalization Plan benefit attributable to supplemental credited service is not vested until age 65. Subject to the approval of the Entergy System company employer, an employee who terminates employment prior to age 65 may be vested in his or her benefit, with payment of the lump sum benefit generally at separation from service unless delayed six months under Internal Revenue Code Section 409A. Benefits payable prior to age 65 are subject to the same reductions as qualified plan benefits.

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The System Executive Retirement Plan

All Named Executive Officers (except Mr. Leonard) are participants in the System Executive Retirement Plan. The System Executive Retirement Plan provides for a single sum payment at age 65, as further described in Compensation Discussion and Analysis. The System Executive Retirement Plan benefit is not vested until age 65. Subject to the approval of the Entergy System company employer, an employee who terminates his or her employment prior to age 65 may be vested in the System Executive Retirement Plan benefit, with payment of the lump sum benefit generally at separation from service unless delayed six months under Internal Revenue Code Section 409A. Benefits payable prior to age 65 are subject to the same reductions as qualified plan benefits. Further, in the event of a change in control, participants whose employment is terminated without “Cause” or for “Good Reason,” as defined in the Plan are also eligible for a subsidized lump sum benefit payment, even if they do not currently meet the age or service requirements for early retirement under that plan or have company permission to separate from employment. Such lump sum benefit is payable generally at separation from service unless delayed 6 months under Internal Revenue Code Section 409A.

Mr. Leonard’s Non-qualified Supplemental Retirement Benefit

Mr. Leonard’s retention agreement provides that if his employment with the Company is terminated for any reason other than for cause (as defined below under “Potential Payments Upon Termination or Change in Control”), he will be entitled to a non-qualified supplemental retirement benefit in lieu of participation in Entergy Corporation’s non-qualified supplemental retirement plans such as the System Executive Retirement Plan or the Pension Equalization Plan. Mr. Leonard’s non-qualified supplemental retirement benefit is calculated as a single life annuity equal to 60% of his final three-year average compensation (as described in the description of the System Executive Retirement Plan included in Compensation Discussion and Analysis), reduced to account for benefits payable to Mr. Leonard under Entergy Corporation’s and a former employer’s qualified pension plans. The benefit is payable in a single lump sum. Because Mr. Leonard has already attained the age of 55, he is currently entitled under his retention agreement to his non-qualified supplemental retirement benefit if he were to leave Entergy System company employment other than as the result of a termination for cause.

Additional Information

For a description of the material terms and conditions of payments and benefits available under the retirement plans, including each plan’s normal retirement payment and benefit, benefit formula and eligibility standards, specific elements of compensation included in applying the payment and benefit formula, and Entergy Corporation’s policies with regard to granting extra years of credited service, see “Compensation Discussion and Analysis -- Benefits, Perquisites, Agreements and Post-Termination Plans -- Pension Plan, Pension Equalization Plan and System Executive Retirement Plan.” For a discussion of the relevant assumptions used in valuing these liabilities, see Note 11 to the Financial Statements.

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2011 Non-qualified Deferred Compensation

The Executive Deferred Compensation Plan, the Amended and Restated 1998 Equity Ownership Plan of Entergy Corporation and Subsidiaries (the 1998 Equity Ownership Plan), the 2007 Equity Ownership Plan and the 2011 Equity Ownership Plan allow for the deferral of compensation for the Named Executive Officers. As of December 31, 2011 none of the Named Executive Officers had deferred compensation balances under the equity ownership plans or the Executive Deferred Compensation Plan. For additional information, see “Benefits, Perquisites, Agreements and Post-Termination Plans - Executive Deferred Compensation” in Compensation Discussion and Analysis. All Named Executive Officers are eligible to participate in the deferral programs.

As of December 31, 2011, Mr. Leonard had a deferred account balance under a frozen Defined Contribution Restoration Plan. These amounts are deemed invested, as chosen by the participant, in certain T. Rowe Price investment funds that are also available to participants under the qualified Savings Plan. The Defined Contribution Restoration Plan, until it was frozen in 2005, credited eligible employees’ deferral accounts with employer contributions to the extent contributions under the qualified savings plan in which the employee participated were subject to limitations imposed by the Internal Revenue Code.

All deferrals are credited to the applicable Entergy System company employer’s non-funded liability account. Depending on the plan under which the deferral is made, the Named Executive Officers may elect investment in either phantom Entergy Corporation common stock or one or more of several investment options available under the Savings Plan. Within limitations of the program, participating Named Executive Officers may move funds from one deemed investment option to another. The participating Named Executive Officers do not have the ability to withdraw funds from the deemed investment accounts except within the terms provided in their deferral elections. Within the limitations prescribed by law as well as the plan, participating Named Executive Officers with deferrals under the Executive Deferred Compensation Plan and/or the equity plans have the option to make a successive deferral of these funds. Assuming a Named Executive Officer does not elect a successive deferral, the Entergy System company employer of the participant is obligated to pay the amount credited to the participant’s account at the earlier of deferral receipt date or separation from service. These payments are paid out of the general assets of the employer and are payable in a lump sum.

Defined Contribution Restoration Plan

Name (a)	Executive Contributions in 2011 (b)	Registrant Contributions in 2011 (c)	Aggregate Earnings in 2011 (1) (d)	Aggregate Withdrawals/ Distributions (e)	Aggregate Balance at December 31, 2011 (f)

J. Wayne Leonard	$ -	$ -	$17,233	$ -	$227,331

(1)	Amounts in this column are not included in the Summary Compensation Table.

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Potential Payments upon Termination or Change in Control

Estimated Payments

The tables below reflect the amount of compensation each of the Named Executive Officers would have received if his employment with Entergy had been terminated under various scenarios as of December 31, 2011. For purposes of these tables, the assumed stock price was $73.05, the closing market price on December 30, 2011, the last business day of the most recently ended fiscal year.

Theodore H. Bunting, Jr

Senior Vice President, Chief Accounting Officer

The following table shows certain payments and benefits, excluding vested or earned awards and benefits, which the Senior Vice President, Chief Accounting Officer would have been entitled to receive as a result of a termination of his employment under various scenarios as of December 31, 2011:

Benefits and Payments Upon Termination(1)	Voluntary Resignation	For Cause	Termination for Good Reason or Not for Cause	Retirement(7)	Disability	Death	Change in Control(8)	Termination Related to a Change in Control
Benefits and Payments Upon Termination(1)	Voluntary Resignation	For Cause	Termination for Good Reason or Not for Cause	Retirement(7)	Disability	Death	Change in Control(8)	Termination Related to a Change in Control

Severance Payment(2)	---	---	---	---	---	---	---	$1,149,469
Performance Units:(3)
2010-2012 Performance Unit Program	---	---	---	---	$107,164	$107,164	$160,710	$160,710
2011-2013 Performance Unit Program	---	---	---	---	$60,851	$60,851	---	$127,838
Unvested Stock Options(4)	---	---	---	---	$1,768	$1,768	---	$1,768
Unvested Restricted Stock(5)	---	---	---	---	$41,398	$41,398	---	$134,191

Medical and Dental Benefits(6)	---	---	---	---	---	---	---	$25,686
280G Tax Gross-up(9)	---	---	---	---	---	---	---	---

(1)

In addition to the payments and benefits in the table, if Mr. Bunting's employment were terminated under certain conditions relating to a change in control, Mr. Bunting also would have been entitled to receive his vested pension benefits and would have been eligible for early retirement benefits. For a description of the pension benefits see "2011 Pension Benefits." If Mr. Bunting's employment were terminated for cause, he would forfeit his benefit under the System Executive Retirement Plan.

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(2)	In the event of a qualifying termination related to a change in control, Mr. Bunting would be entitled to receive pursuant to the System Executive Continuity Plan a lump sum severance payment equal to the product of two times the sum of (a) his annual base salary as in effect at any time within one year prior to the commencement of a of a change in control period or, if higher, immediately prior to a circumstance constituting good reason plus (b) his annual incentive, calculated using the average annual target opportunity derived under the Executive Incentive Plan for the two calendar years immediately preceding the calendar year in which the participant’s termination occurs. For purposes of this table, a 60% target opportunity and a base salary of $359,209 was assumed.
(3)	In the event of a change in control (regardless of whether he experienced a qualifying termination), Mr. Bunting would have been entitled, pursuant to the 2007 Equity Ownership Plan, to receive for the 2010-2012 performance period a lump sum payment relating to his performance units. The payment is calculated as if all performance goals relating to the performance units were achieved at target level. For purposes of the table, the value of Mr. Bunting's award was calculated as follows: 2010 - 2012 Plan – 2,200 performance units at target, assuming a stock price of $73.05 In the event of a qualifying termination related to a change in control, Mr. Bunting would have forfeited his performance units for the 2011-2013 performance period and would have been entitled to receive, pursuant to the 2007 Equity Ownership Plan, a single-sum severance payment that would not be based on any outstanding performance periods. For the 2011-2013 performance period, the payment would have been calculated using the average annual number of performance units he would have been entitled to receive under the Performance Unit Program with respect to the two most recent performance periods preceding the calendar year in which his termination occurs, assuming all performance goals were achieved at target. For purposes of the table, the value of Mr. Bunting’s severance payment was calculated by taking an average of the target performance units from the 2007-2009 Performance Unit Program (2,100 units) and the 2008-2010 Performance Unit Program (1,400 units) and multiplying the average number of units (1,750 units) by the closing price of Entergy common stock on December 30, 2011 ($73.05) resulting in a severance payment of $127,838 for the forfeited performance units. In the event of Mr. Bunting’s death or disability not related to a change in control, Mr. Bunting would not have forfeited his performance units for all open performance periods, but rather such performance unit awards would have been pro-rated based on his number of months of participation in each open Performance Unit Program performance cycle. The amount of the award is based on actual performance achieved, with a stock price set as of the end of the performance period, and payable in the form of a lump sum after the completion of the performance period. For purposes of the table, the value of Mr. Bunting's awards were calculated as follows: 2010 - 2012 Plan – 1,467 (2,200 * 24/36) performance units at target, assuming a stock price of $73.05 2011 - 2013 Plan – 833 (2,500 *12/36) performance units at target, assuming a stock price of $73.05
(4)	In the event of his death, disability or a change in control, all of Mr. Bunting's unvested stock options granted prior to December 30, 2010 would immediately vest. In the event of his death, disability or qualifying termination related to a change in control, all of Mr. Bunting’s unvested stock options granted on or after December 30, 2010 would immediately vest. In addition, he would be entitled to exercise his stock options for the remainder of the ten-year extending from the grant date of the options. For purposes of this table, it is assumed that Mr. Bunting exercised his options immediately upon vesting and received proceeds equal to the difference between the closing price of common stock on December 30, 2011, and the applicable exercise price of each option share. As of December 31, 2011, the closing stock price exceeded the exercise price for Mr. Bunting’s 2011 unvested options and accordingly, such options are reported in the table; all other stock options with respect to the accelerated vesting of Mr. Bunting’s stock options were “underwater” as of December 31, 2011 and are excluded from the table.

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(5)	In the event of his death or disability, Mr. Bunting would immediately vest in a pro-rated portion of the unvested restricted stock that was otherwise scheduled to become vested on the immediately following twelve (12)-month grant date anniversary date (as well as dividends declared on the pro-rated portion of such restricted stock). The pro-rated vested portion would be determined based on the number of days between the most recent preceding twelve (12)-month Grant Date anniversary date and the date of his death or Disability. In the event of his qualifying termination related to a change in control, Mr. Bunting would immediately vest in all unvested restricted stock.
(6)	Pursuant to the System Executive Continuity Plan, in the event of a termination related to a change in control, Mr. Bunting would be eligible to receive Entergy-subsidized COBRA benefits for 18 months.
(7)	As of December 31, 2011, compensation and benefits available to Mr. Bunting under this scenario are substantially the same as available with a voluntary resignation. As of December 31, 2011, Mr. Bunting is not retirement eligible.
(8)	With respect to grants made under the 2007 Equity Ownership Plan prior to December 30, 2010, plan participants are entitled to receive an acceleration of certain benefits based solely upon a change in control of Entergy and without regard to whether their employment is terminated as a result of a change in control. The accelerated benefits in the event of a change in control are as follows: · All unvested stock options would become immediately exercisable; and · Severance benefits in place of performance units become payable as described in footnote 3 above. The 2007 Equity Ownership Plan was amended in December 2010 so that awards granted on or after December 30, 2010 require a qualifying involuntary termination in order to accelerate vesting or trigger severance payment upon a change in control.
(9)	In December 2010, the System Executive Continuity Plan was amended to eliminate excise tax gross up payments.

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Leo P. Denault

Executive Vice President and Chief Financial Officer

The following table shows certain payments and benefits, excluding vested or earned awards and benefits, which the Executive Vice President and Chief Financial Officer would have been entitled to receive as a result of a termination of his employment under various scenarios as of December 31, 2011:

Benefits and Payments Upon Termination(1)	Voluntary Resignation	For Cause	Termination for Good Reason or Not for Cause	Retirement(9)	Disability	Death	Change in Control(10)	Termination Related to a Change in Control
Benefits and Payments Upon Termination(1)	Voluntary Resignation	For Cause	Termination for Good Reason or Not for Cause	Retirement(9)	Disability	Death	Change in Control(10)	Termination Related to a Change in Control
Severance Payment(2)	---	---	$3,330,382	---	---	---	---	$3,330,382
Performance Units:(3)
2010-2012 Performance Unit Program	---	---	$306,810	---	$306,810	$306,810	---	$306,810
2011-2013 Performance Unit Program	---	---	$306,810	---	$306,810	$306,810	---	$306,810
Unvested Stock Options(4)	---	---	$6,500	---	$6,500	$6,500	---	$6,500
Unvested Restricted Stock(5)	---	---	$383,402	---	$383,402	$383,402	--	$383,402
Unvested Restricted Units(6)	---		$1,168,800	---	$1,168,800	$1,168,800	--	$1,168,800

COBRA Benefits(7)	---	---	$25,686	---	---	---	---	---
Medical and Dental Benefits(8)	---	---	---	---	---	---	---	$25,686
280G Tax Gross-up(11)	---	---	---	---	---	---	---	---

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(1)		In addition to the payments and benefits in the table, Mr. Denault also would have been entitled to receive his vested pension benefits. If Mr. Denault’s employment were terminated under certain conditions relating to a change in control, he would also be eligible for early retirement benefits. For a description of these benefits, see “2011 Pension Benefits.” In addition, Mr. Denault is subject to the following provisions: · Retention Agreement. Mr. Denault’s retention agreement provides that, unless his employment is terminated for cause, he will be granted an additional 15 years of service under the System Executive Retirement Plan if he continues to work for an Entergy System company employer until age 55. Because Mr. Denault had not reached age 55 as of December 31, 2010, he is only entitled to this supplemental credited service and System Executive Retirement Plan supplemental benefits in the event of his death or disability. · System Executive Retirement Plan. If Mr. Denault’s employment were terminated for cause, he would forfeit his benefit under the System Executive Retirement Plan. In the event of a termination related to a change in control, pursuant to the terms of the System Executive Retirement Plan, Mr. Denault would be eligible for subsidized retirement (but not the additional 15 years of service) upon his separation of service even if he does not then meet the age or service requirements for early retirement under the System Executive Retirement Plan or have company permission to separate from employment.
(2)		In the event of a termination (not due to death or disability) by Mr. Denault for good reason or by Entergy not for cause (regardless of whether there is a change in control), Mr. Denault would be entitled to receive, pursuant to his retention agreement, a lump sum severance payment equal to the product of 2.99 times the sum of (a) his annual base salary as in effect at any time within one year prior to the effective date of the Agreement (i.e., 2007) or, if higher, immediately prior to a circumstance constituting good reason plus (b) the greater of (i) his actual annual incentive award under the Annual Incentive Plan for the calendar year immediately preceding the calendar year in which Mr. Denault’s termination date occurs or (ii) Mr. Denault’s Annual Incentive Plan target award for the calendar year in which the effective date of the Agreement occurred (i.e., 2007). For purposes of this table, the award was calculated using a base salary of $655,200 and target award of 70%.

(3)

In the event of a termination due to death or disability, by Mr. Denault for good reason, or by Entergy not for cause (in all cases, regardless of whether there is a change in control), Mr. Denault would have forfeited his performance units for all open performance periods and would have been entitled to receive a single-sum severance payment pursuant to his retention agreement that would not be based on any outstanding performance periods. The payment would be calculated using the average annual number of performance units he would have been entitled to receive under the Performance Unit Program with respect to the two most recent performance periods preceding the calendar year in which his termination occurs, assuming all performance goals were achieved at target. For purposes of the table, the value of Mr. Denault's severance payment was calculated by taking an average of the target performance units from the 2007-2009 Performance Unit Program (4,500 units) and the 2008-2010 Performance Unit Program (3,900 units) and multiplying the average number of units (4,200 units) by the closing price of Entergy common stock on December 30, 2011 ($73.05) resulting in a severance payment of $306,810 for the forfeited performance units.

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(4)		In the event of his death, disability, termination by Mr. Denault for good reason or by Entergy not for cause (regardless of whether there is a change in control), all of Mr. Denault’s unvested stock options would immediately vest. In addition, he would be entitled to exercise any unexercised options during a ten-year term extending from the grant date of the options. For purposes of this table, it was assumed that Mr. Denault exercised his options immediately upon vesting and received proceeds equal to the difference between the closing price of common stock on December 30, 2011, and the exercise price of each option share. As of December 31, 2011, the closing stock price exceeded the exercise price for Mr. Denault’s 2011 unvested options and accordingly, such options are reported in the table; all other stock options with respect to the accelerated vesting of Mr. Denault’s stock options were “underwater” as of December 31, 2011 and are excluded from the table.
(5)		In the event of his death, disability, termination by Mr. Denault for good reason or by Entergy not for cause (regardless of whether there is a change in control), all of Mr. Denault’s unvested restricted stock would immediately vest.
(6)		Pursuant to his restricted unit agreement, any unvested restricted units will vest immediately in the event of a change in control, Mr. Denault’s death or disability, or termination of employment by Mr. Denault for good reason or by Entergy not for cause (regardless of whether there is a change in control).
(7)		Pursuant to his retention agreement, in the event of a termination by Mr. Denault for good reason or by Entergy not for cause, Mr. Denault would be eligible to receive Entergy-subsidized COBRA benefits for 18 months.
(8)		Pursuant to the System Executive Continuity Plan, in the event of a termination related to a change in control, Mr. Denault would be eligible to receive Entergy-subsidized medical and dental benefits for 18 months.
(9)		As of December 31, 2011, Mr. Denault is not eligible for retirement.
(10)		The 2007 Equity Ownership Plan was amended in December 2010 so that awards granted after December 30, 2010 require an involuntary termination in order to accelerate vesting or trigger severance payments upon a change in control.
(11)		In December 2010, Mr. Denault voluntarily agreed to amend his retention agreement to eliminate excise tax gross up payments.

Under the terms of Mr. Denault’s retention agreement, Entergy may terminate his employment for cause upon Mr. Denault’s:

·	continuing failure to substantially perform his duties (other than because of physical or mental illness or after he has given notice of termination for good reason) that remains uncured for 30 days after receiving a written notice from the Personnel Committee;

·	willfully engaging in conduct that is demonstrably and materially injurious to Entergy;

·	conviction of or entrance of a plea of guilty or nolo contendere to a felony or other crime that has or may have a material adverse effect on his ability to carry out his duties or upon Entergy’s reputation;

·	material violation of any agreement that he has entered into with Entergy; or

·	unauthorized disclosure of Entergy’s confidential information.

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Mr. Denault may terminate his employment for good reason upon:

·	the substantial reduction in the nature or status of his duties or responsibilities;

·	a reduction of 5% or more in his base salary as in effect on the date of the retention agreement;

·	the relocation of his principal place of employment to a location other than the corporate headquarters;

the failure to continue to allow him to participate in programs or plans providing opportunities for equity awards, stock options, restricted stock, stock appreciation rights, incentive compensation, bonus and other plans on a basis not materially less favorable than enjoyed at the time of the retention agreement (other than changes similarly affecting all senior executives);

the failure to continue to allow him to participate in programs or plans with opportunities for benefits not materially less favorable than those enjoyed by him under any of the pension, savings, life insurance, medical, health and accident, disability or vacation plans at the time of the retention agreement (other than changes similarly affecting all senior executives); or

·	any purported termination of his employment not taken in accordance with his retention agreement.

Mr. Denault may terminate his employment for good reason in the event of a change in control upon:

·	the substantial reduction or alteration in the nature or status of his duties or responsibilities;

·	a reduction in his annual base salary;

·	the relocation of his principal place of employment to a location more than 20 miles from his current place of employment;

·	the failure to pay any portion of his compensation within seven days of its due date;

·	the failure to continue in effect any compensation plan in which he participates and which is material to his total compensation, unless other equitable arrangements are made;

the failure to continue to provide benefits substantially similar to those that he currently enjoys under any of the pension, savings, life insurance, medical, health and accident or disability plans, or Entergy taking of any other action which materially reduces any of those benefits or deprives him of any material fringe benefits that he currently enjoys;

·	the failure to provide him with the number of paid vacation days to which he is entitled in accordance with the normal vacation policy; or

·	any purported termination of his employment not taken in accordance with his retention agreement

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Joseph F. Domino

President & CEO - Entergy Texas

The following table shows certain payments and benefits, excluding vested or earned awards and benefits, which the President and CEO – Entergy Texas would have been entitled to receive as a result of a termination of his employment under various scenarios as of December 31, 2011:

Benefits and Payments Upon Termination(1)	Voluntary Resignation	For Cause	Termination for Good Reason or Not for Cause	Retirement(7)	Disability	Death	Change in Control(8)	Termination Related to a Change in Control
Benefits and Payments Upon Termination(1)	Voluntary Resignation	For Cause	Termination for Good Reason or Not for Cause	Retirement(7)	Disability	Death	Change in Control(8)	Termination Related to a Change in Control
Severance Payment(2)	---	---	---	---	---	---	---	$486,156
Performance Units:(3)
2010-2012 Performance Unit Program	---	---	---	$48,724	$48,724	$48,724	$73,050	$73,050
2011-2013 Performance Unit Program	---	---	---	$29,220	$29,220	$29,220	---	$62,093
Unvested Stock Options(4)	---	---	---	$754	$754	$754	---	$754
Unvested Restricted Stock(5)	---	---	---	---	$21,302	$21,302		$69,012
Medical and Dental Benefits(6)	---	---	---	---	---	---	---	---
280G Tax Gross-up(9)	---	---	---	---	---	---	---	---

(1)

In addition to the payments and benefits in the table, Mr. Domino would have been eligible to retire and entitled to receive his vested pension benefits. For a description of the pension benefits available see "2011 Pension Benefits." In the event of a termination related to a change in control, pursuant to the terms of the System Executive Retirement Plan, Mr. Domino would be eligible for subsidized early retirement even if he does not have company permission to separate from employment. If Mr. Domino’s employment were terminated for cause, he would not receive a benefit under the System Executive Retirement Plan.

(2)

In the event of a qualifying termination related to a change in control, Mr. Domino would be entitled to receive pursuant to the System Executive Continuity Plan a lump sum severance payment equal to the product of one time the sum of (a) his annual base salary as in effect at any time within one year prior to the commencement of a change in control period or, if higher, immediately prior to a circumstance constituting good reason plus (b) his annual incentive, calculated using the average annual target opportunity derived under the Annual Incentive Plan for the two calendar years immediately preceding the calendar year in which the participant’s termination occurs. For purposes of this table, a 50% target opportunity and a base salary of $324,104 was assumed.

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(3)	In the event of a change in control (regardless of whether he experienced a qualifying termination), Mr. Domino would have been entitled, pursuant to the 2007 Equity Ownership Plan, to receive for the 2010-2012 performance period a lump sum payment relating to his performance units. The payment is calculated as if all performance goals relating to the performance units were achieved at target level. For purposes of the table, the value of Mr. Domino's award was calculated as follows: 2010 - 2012 Plan – 1,000 performance units at target, assuming a stock price of $73.05 In the event of a qualifying termination related to a change in control, Mr. Domino would have forfeited his performance units for the 2011-2013 performance period and would have been entitled to receive, pursuant to the 2007 Equity Ownership Plan, a single-sum severance payment that would not be based on any outstanding performance periods. For the 2011-2013 performance period, the payment would have been calculated using the average annual number of performance units he would have been entitled to receive under the Performance Unit Program with respect to the two most recent performance periods preceding the calendar year in which his termination occurs, assuming all performance goals were achieved at target. For purposes of the table, the value of Mr. Domino’s severance payment was calculated by taking an average of the target performance units from the 2007-2009 Performance Unit Program (1,000 units) and the 2008-2010 Performance Unit Program (700 units) and multiplying the average number of units (850 units) by the closing price of Entergy common stock on December 30, 2011 ($73.05) resulting in a severance payment of $ $62,093 for the forfeited performance units. In the event of Mr. Domino’s death, disability or retirement not related to a change in control, Mr. Domino would not have forfeited his performance units for all open performance periods, but rather such performance unit awards would have been pro-rated based on his number of months of participation in each open Performance Unit Program performance cycle. The amount of the award is based on actual performance achieved, with a stock price set as of the end of the performance period, and payable in the form of a lump sum after the completion of the performance period. For purposes of the table, the value of Mr. Domino's awards were calculated as follows: 2010 - 2012 Plan – 667 (1,000 * 24/36) performance units at target, assuming a stock price of $73.05 2011 - 2013 Plan – 400 (1,200 * 12/36) performance units at target, assuming a stock price of $73.05
(4)	In the event of his retirement, death, disability or a change in control, all of Mr. Domino’s unvested stock options granted prior to December 31, 2010 would immediately vest. In the event of his retirement, death, disability or qualifying termination related to a change in control, all of Mr. Domino’s unvested stock options granted on or after December 30, 2010 would immediately vest. In addition, he would be entitled to exercise his stock options for a ten-year term extending from the grant date of the options. For purposes of this table, it was assumed that Mr. Domino exercised his options immediately upon vesting and received proceeds equal to the difference between the closing price of common stock on December 30, 2011, and the exercise price of each option share. As of December 31, 2011, the closing stock price exceeded the exercise price for Mr. Domino’s 2011 unvested options and accordingly, such options are reported in the table; all other stock options with respect to the accelerated vesting of Mr. Domino’s stock options were “underwater” as of December 31, 2011 and are excluded from the table.
(5)	In the event of his death or disability, Mr. Domino would immediately vest in a pro-rated portion of the unvested restricted stock that was otherwise scheduled to become vested on the immediately following twelve (12)-month grant date anniversary date (as well as dividends declared on the pro-rated portion of such restricted stock). The pro-rated vested portion would be determined based on the number of days between the most recent preceding twelve (12)-month Grant Date anniversary date and the date of his death or Disability. In the event of his qualifying termination related to a change in control, Mr. Domino would immediately vest in all unvested restricted stock.
(6)	Upon retirement Mr. Domino would be eligible for retiree medical and dental benefits at the same level as all other retirees. Pursuant to the System Executive Continuity Plan, in the event of a termination related to a change in control, Mr. Domino would not be eligible to receive Entergy subsidized COBRA benefits.

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(7)	As of December 31, 2011, Mr. Domino is retirement eligible and would retire rather than voluntarily resign. Given that scenario, the compensation and benefits available to Mr. Domino under retirement are substantially the same as available with a voluntary resignation.
(8)	With respect to grants made under the 2007 Equity Ownership Plan prior to December 30, 2010, plan participants are entitled to receive an acceleration of certain benefits based solely upon a change in control of Entergy and without regard to whether their employment is terminated as a result of a change in control. The accelerated benefits in the event of a change in control are as follows: · All unvested stock options would become immediately exercisable; and · Severance benefits in place of performance units become payable as described in footnote 3 above. The 2007 Equity Ownership Plan was amended in December 2010 so that awards granted on or after December 30, 2010 require a qualifying involuntary termination in order to accelerate vesting or trigger severance payments.
(9)	In December 2010, the System Executive Continuity Plan was amended to eliminate excise tax gross up payments.

Haley R. Fisackerly

President & CEO - Entergy Mississippi

The following table shows certain payments and benefits, excluding vested or earned awards and benefits, which the President and CEO - Entergy Mississippi would have been entitled to receive as a result of a termination of his employment under various scenarios as of December 31, 2011:

Benefits and Payments Upon Termination(1)	Voluntary Resignation	For Cause	Termination for Good Reason or Not for Cause	Retirement(7)	Disability	Death	Change in Control(8)	Termination Related to a Change in Control
Benefits and Payments Upon Termination(1)	Voluntary Resignation	For Cause	Termination for Good Reason or Not for Cause	Retirement(7)	Disability	Death	Change in Control(8)	Termination Related to a Change in Control
Severance Payment(2)	---	---	---	---	---	---	---	$396,550
Performance Units:(3)
2010-2012 Performance Unit Program	---	---	---	---	$48,724	$48,724	$73,050	$73,050
2011-2013 Performance Unit Program	---	---	---	---	$29,220	$29,220	---	$62,093
Unvested Stock Options(4)	---	---	---	---	$754	$754	---	$754
Unvested Restricted Stock(5)	---	---	---	---	$21,302	$21,302	---	$69,012
Medical and Dental Benefits(6)	---	---	---	---	---	---	---	$17,124
280G Tax Gross-up(9)	---	---	---	---	---	---	---	---

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(1)		In addition to the payments and benefits in the table, if Mr. Fisackerly's employment were terminated under certain conditions relating to a change in control, Mr. Fisackerly also would have been entitled to receive his vested pension benefits and would have been eligible for early retirement benefits. For a description of the pension benefits see "2011 Pension Benefits." If Mr. Fisackerly's employment were terminated for cause, he would forfeit his benefit under the System Executive Retirement Plan.
(2)		In the event of a qualifying termination related to a change in control, Mr. Fisackerly would be entitled to receive pursuant to the System Executive Continuity Plan, a lump sum severance payment equal to the product of one time the sum of (a) his annual base salary as in effect at any time within one year prior to the commencement of a of a change in control period or, if higher, immediately prior to a circumstance constituting good reason plus (b) his annual incentive, calculated using the average annual target opportunity derived under the Executive Incentive Plan for the two calendar years immediately preceding the calendar year in which the participant’s termination occurs. For purposes of this table, a 40% target opportunity and a base salary of $283,250 was assumed.
(3)		In the event of a change in control (regardless of whether he experienced a qualifying termination), Mr. Fisackerly would have been entitled, pursuant to the 2007 Equity Ownership Plan, to receive for the 2010-2012 performance period a lump sum payment relating to his performance units. The payment is calculated as if all performance goals relating to the performance units were achieved at target level. For purposes of the table, the value of Mr. Fisackerly’s award was calculated as follows: 2010 - 2012 Plan – 1,000 performance units at target, assuming a stock price of $73.05 In the event of a qualifying termination related to a change in control, Mr. Fisackerly would have forfeited his performance units for the 2011-2013 performance period and would have been entitled to receive, pursuant to the 2007 Equity Ownership Plan, a single-sum severance payment that would not be based on any outstanding performance periods. For the 2011-2013 performance period, the payment would have been calculated using the average annual number of performance units he would have been entitled to receive under the Performance Unit Program with respect to the two most recent performance periods preceding the calendar year in which his termination occurs, assuming all performance goals were achieved at target. For purposes of the table, the value of Mr. Fisackerly’s severance payment was calculated by taking an average of the target performance units from the 2007-2009 Performance Unit Program (1,000 units) and the 2008-2010 Performance Unit Program (700 units) and multiplying the average number of units (850 units) by the closing price of Entergy common stock on December 30, 2011 ($73.05) resulting in a severance payment of $ $62,093 for the forfeited performance units. In the event of Mr. Fisackerly’s death or disability not related to a change in control, Mr. Fisackerly would not have forfeited his performance units for all open performance periods, but rather such performance unit awards would have been pro-rated based on his number of months of participation in each open Performance Unit Program performance cycle. The amount of the award is based on actual performance achieved, with a stock price set as of the end of the performance period, and payable in the form of a lump sum after the completion of the performance period. For purposes of the table, the value of Mr. Fisackerly's awards were calculated as follows: 2010 - 2012 Plan – 667 (1,000 * 24/36) performance units at target, assuming a stock price of $73.05 2011 - 2013 Plan – 400 (1,200 * 12/36) performance units at target, assuming a stock price of $73.05

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(4)	In the event of his death, disability or a change in control, all of Mr. Fisackerly's unvested stock options granted prior to December 30, 2010 would immediately vest. In the event of his death, disability or qualifying termination related to a change in control, all of Mr. Fisackerly’s unvested stock options granted on or after December 30, 2010 would immediately vest. In addition, he would be entitled to exercise his stock options for the remainder of the ten-year extending from the grant date of the options. For purposes of this table, it is assumed that Mr. Fisackerly exercised his options immediately upon vesting and received proceeds equal to the difference between the closing price of common stock on December 30, 2011, and the applicable exercise price of each option share. As of December 31, 2011, the closing stock price exceeded the exercise price for Mr. Fisackerly’s 2011 unvested options and accordingly, such options are reported in the table; all other stock options with respect to the accelerated vesting of Mr. Fisackerly’s stock options were “underwater” as of December 31, 2011 and are excluded from the table.
(5)	In the event of his death or disability, Mr. Fisackerly would immediately vest in a pro-rated portion of the unvested restricted stock that was otherwise scheduled to become vested on the immediately following twelve (12)-month grant date anniversary date (as well as dividends declared on the pro-rated portion of such restricted stock). The pro-rated vested portion would be determined based on the number of days between the most recent preceding twelve (12)-month Grant Date anniversary date and the date of his death or Disability. In the event of his qualifying termination related to a change in control, Mr. Fisackerly would immediately vest in all unvested restricted stock.
(6)	Pursuant to the System Executive Continuity Plan, in the event of a termination related to a change in control, Mr. Fisackerly would be eligible to receive Entergy- subsidized COBRA benefits for 12 months.
(7)	As of December 31, 2011, compensation and benefits available to Mr. Fisackerly under this scenario are substantially the same as available with a voluntary resignation. As of December 31, 2011, Mr. Fisackerly is not retirement eligible.
(8)	With respect to grants made under the 2007 Equity Ownership Plan prior to December 30, 2010, plan participants are entitled to receive an acceleration of certain benefits based solely upon a change in control of Entergy and without regard to whether their employment is terminated as a result of a change in control. The accelerated benefits in the event of a change in control are as follows: · All unvested stock options would become immediately exercisable; and · Severance benefits in place of performance units become payable as described in footnote 3 above. The 2007 Equity Ownership Plan was amended in December 2010 so that awards granted on or after December 30, 2010 require a qualifying involuntary termination in order to accelerate vesting or trigger severance payments.
(9)	In December 2010, the System Executive Continuity Plan was amended to eliminate excise tax gross up payments.

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J. Wayne Leonard

Chairman and Chief Executive Officer

The following table shows certain payments and benefits, excluding vested or earned awards and benefits, which Entergy's Chairman and Chief Executive Officer would have been entitled to receive as a result of a termination of his employment under various scenarios as of December 31, 2011:

Benefits and Payments Upon Termination(1)	Voluntary Resignation	For Cause	Termination for Good Reason or Not for Cause	Retirement(9)	Disability	Death	Change in Control(10)	Termination Related to a Change in Control
Benefits and Payments Upon Termination(1)		For Cause	Termination for Good Reason or Not for Cause	Retirement(9)	Disability	Death	Change in Control(10)	Termination Related to a Change in Control
Annual Incentive Payment(2)	---	---	---	---	---	---	---	$3,177,120
Severance Payment(3)	---	---	---	---	---	---	---	$8,707,956
Performance Units:(4)
2010-2012 Performance Unit Program	---	---	---	$1,086,034	$1,086,034	$1,086,034	---	$1,471,958
2011-2013 Performance Unit Program	---	---	---	$633,124	$633,124	$633,124	---	$1,471,958
Unvested Stock Options(5)	---	---	---	$18,200	$18,200	$18,200	---	$18,200
Unvested Restricted Stock(6)	---	---	---	---	$272,198	$272,198	---	$881,825
Unvested Restricted Units (7)	---	---	$3,652,500	---	$3,652,500	$3,652,500	---	$3,652,500

Medical and Dental Benefits(8)	---	---	---	---	---	---	---	---
280G Tax Gross-up(11)	---	---	---	---	---	---	---	---

(1)

In addition to the payments and benefits in the table, Mr. Leonard would have been eligible to retire and entitled to receive his vested pension benefits. However, a termination “for cause” would have resulted in forfeiture of Mr. Leonard’s supplemental retirement benefit. Mr. Leonard is not entitled to additional pension benefits upon the occurrence of a change in control. For additional information regarding these vested benefits and awards, see “2011 Pension Benefits.”

(2)

In the event of a qualifying termination related to a change in control, Mr. Leonard would have been entitled under his retention agreement to receive a lump sum severance payment equal to Mr. Leonard’s average maximum annual bonus opportunity under the Annual Incentive Plan for Entergy’s two calendar years immediately preceding the calendar year in which his termination occurs. For purposes of this table, the award was calculated at 200% of target opportunity and the base salary was assumed to be $1,323,800.

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(3)	In the event of a qualifying termination related to a change in control, Mr. Leonard would have been entitled to receive pursuant to his retention agreement a lump sum severance payment equal to the product of 2.99 times the sum of his (a) annual base salary plus (b) his target Annual Incentive Plan award for any fiscal year (other than the fiscal year in which his date of termination occurs) ending after the effective date of his retention agreement.
(4)	In the event of a qualifying termination related to a change in control, including a termination by Mr. Leonard for good reason, by Entergy other than cause, disability or death, Mr. Leonard would have forfeited his performance units for all open performance periods and would have been entitled to receive a single sum severance payment pursuant to his retention agreement that would not be based on any outstanding performance periods. The payment would have been calculated using the average annual number of performance units he would have been entitled to receive under the Performance Unit Program with respect to the two most recent performance periods preceding the calendar year in which his termination occurs, assuming all performance goals were achieved at target. For purposes of the table, the value of Mr. Leonard's severance payment was calculated by taking an average of the target performance units from the 2007-2009 Performance Unit Program (23,800 units) and the 2008-2010 Performance Unit Program (16,500 units) and multiplying the average number of units (20,150 units) by the closing price of Entergy common stock on December 30, 2011 ($73.05) resulting in a severance payment of $1,471,958 for the forfeited performance units. In the event of Mr. Leonard’s death, disability or retirement not related to a change in control, Mr. Leonard would not have forfeited his performance units for all open performance period, but rather such performance unit awards would have been pro-rated based on his number of months of participation in each open Performance Unit Program performance cycle. The amount of the award is based on actual performance achieved, with a stock price set as of the end of the performance period, and payable in the form of a lump sum after the completion of the performance period. 2010 - 2012 Plan – 14,867 (22,300 * 24/36) performance units at target, assuming a stock price of $73.05 2011 - 2013 Plan – 8,667 (26,000 * 12/36) performance units at target, assuming a stock price of $73.05
(5)	In the event of retirement, death, disability or a qualifying termination related to a change in control, all of Mr. Leonard’s unvested stock options would immediately vest. In addition, Mr. Leonard would be entitled to exercise any outstanding options during a ten-year term extending from the grant date of the options. For purposes of this table, it was assumed that Mr. Leonard exercised his options immediately upon vesting and received proceeds equal to the difference between the closing price of common stock on December 30, 2011, and the exercise price of each option share. As of December 31, 2011, the closing stock price exceeded the exercise price for Mr. Leonard’s 2011 unvested options and accordingly, such options are reported in the table; all other stock options with respect to the accelerated vesting of Mr. Leonard’s stock options were “underwater” as of December 31, 2011 and are excluded from the table.
(6)	In the event of a qualifying termination related to a change in control, all of Mr. Leonard’s unvested restricted stock would immediately vest. In the event of Mr. Leonard’s death or disability, restrictions would lift on a pro-rated portion of his unvested restricted shares that were scheduled to become vested on the immediately following twelve -month grant date anniversary, based on the number of days worked during such twelve-month period.
(7)	Pursuant to his restricted unit agreement, any unvested restricted units will vest immediately in the event of a qualifying termination related to a change in control, termination by Mr. Leonard for good reason, by Entergy other than for cause, or by reason of his death or disability.

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(8)	Upon retirement Mr. Leonard would be eligible for retiree medical and dental benefits at the same level as all other retirees. Pursuant to his retention agreement, in the event of a termination related to a change in control, Mr. Leonard would not be eligible to receive additional subsidized COBRA benefits.
(9)	As of December 31, 2011, Mr. Leonard is retirement eligible and would retire rather than voluntarily resign. Given this scenario, the compensation and benefits available to Mr. Leonard under retirement are substantially the same as available upon voluntary resignation.
(10)	The 2007 Equity Ownership Plan was amended in December 2010 so that awards granted after December 30, 2010 require an involuntary termination in order to accelerate vesting or trigger severance payments upon a change in control.
(11)	In December 2010, Mr. Leonard voluntarily agreed to amend his retention agreement to eliminate excise tax gross up payments.

Under the terms of Mr. Leonard's retention agreement, Entergy may terminate his employment for cause upon Mr. Leonard's:

·	willful and continued failure to substantially perform his duties (other than because of physical or mental illness or after he has given notice of termination for good reason) that remains uncured for 30 days after receiving a written notice from the Board; or

·	willfully engaging in conduct that is demonstrably and materially injurious to us and which results in a conviction of, or entrance of a plea of guilty or nolo contendere (essentially a form of plea in which the accused refuses to contest the charges) to a felony.

In the event of a change in control, Mr. Leonard may terminate his employment for good reason upon:

·	the substantial reduction or alteration in the nature or status of his duties or responsibilities;

·	a reduction in his annual base salary;

·	the relocation of his principal place of employment to a location more than 20 miles from his current place of employment;

·	the failure to pay any portion of his compensation within seven days of its due date;

·	the failure to continue in effect any compensation plan in which he participates and which is material to his total compensation, unless other equitable arrangements are made;

the failure to continue to provide benefits substantially similar to those that he currently enjoys under any of the pension, savings, life insurance, medical, health and accident or disability plans, or the taking of any other action which materially reduces any of those benefits or deprives him of any material fringe benefits that he currently enjoys;

·	the failure to provide him with the number of paid vacation days to which he is entitled in accordance with the normal vacation policy; or

·	any purported termination of his employment not taken in accordance with his retention agreement.

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Hugh T. McDonald

President & CEO, Entergy Arkansas

The following table shows certain payments and benefits, excluding vested or earned awards and benefits, which the President & CEO, Entergy Arkansas would have been entitled to receive as a result of a termination of his employment under various scenarios as of December 31, 2011:

Benefits and Payments Upon Termination(1)	Voluntary Resignation	For Cause	Termination for Good Reason or Not for Cause	Retirement(7)	Disability	Death	Change in Control(8)	Termination Related to a Change in Control
Severance Payment(2)	---	---	---	---	---	---	---	$495,277
Performance Units:(3)
2010-2012 Performance Unit Program	---	---	---	---	$48,724	$48,724	$73,050	$73,050
2011-2013 Performance Unit Program	---	---	---	---	$29,220	$29,220	---	$62,093
Unvested Stock Options(4)	---	---	---	---	$754	$754	---	$754
Unvested Restricted Stock(5)	---	---	---	---	$21,302	$21,302	---	$69,012
Medical and Dental Benefits(6)	---	---	---	---	---	---	---	$17,124
280G Tax Gross-up(9)	---	---	---	---	---	---	---	---

(1)

In addition to the payments and benefits in the table, if Mr. McDonald's employment were terminated under certain conditions relating to a change in control, Mr. McDonald also would have been entitled to receive his vested pension benefits and would have been eligible for early retirement benefits. For a description of the pension benefits see "2011 Pension Benefits." If Mr. McDonald's employment were terminated for cause, he would forfeit his benefit under the System Executive Retirement Plan.

(2)

In the event of a qualifying termination related to a change in control, Mr. McDonald would be entitled to receive pursuant to the System Executive Continuity Plan, a lump sum severance payment equal to the product of one time the sum of (a) his annual base salary as in effect at any time within one year prior to the commencement of a of a change in control period or, if higher, immediately prior to a circumstance constituting good reason plus (b) his annual incentive, calculated using the average annual target opportunity derived under the Executive Incentive Plan for the two calendar years immediately preceding the calendar year in which the participant’s termination occurs. For purposes of this table, a 50% target opportunity and a base salary of $330,185 was assumed.

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(3)	In the event of a change in control (regardless of whether he experienced a qualifying termination), Mr. McDonald would have been entitled to receive pursuant to the 2007 Equity Ownership Plan, to receive for the 2010-2012 performance period a lump sum payment relating to his performance units. The payment is calculated as if all performance goals relating to the performance units were achieved at target level. For purposes of the table, the value of Mr. McDonald’s award was calculated as follows: 2010 - 2012 Plan – 1,000 performance units at target, assuming a stock price of $73.05 In the event of a qualifying termination related to a change in control, Mr. McDonald would have forfeited his performance units for the 2011-2013 performance period and would have been entitled to receive, pursuant to the 2007 Equity Ownership Plan, a single-sum severance payment that would not be based on any outstanding performance periods. For the 2011-2013 performance period, the payment would have been calculated using the average annual number of performance units he would have been entitled to receive under the Performance Unit Program with respect to the two most recent performance periods preceding the calendar year in which his termination occurs, assuming all performance goals were achieved at target. For purposes of the table, the value of Mr. McDonald’s severance payment was calculated by taking an average of the target performance units from the 2007-2009 Performance Unit Program (1,000 units) and the 2008-2010 Performance Unit Program (700 units) and multiplying the average number of units (850 units) by the closing price of Entergy common stock on December 30, 2011 ($73.05) resulting in a severance payment of $ $62,093 for the forfeited performance units. In the event of Mr. McDonald’s death or disability not related to a change in control, Mr. McDonald would not have forfeited his performance units for all open performance periods, but rather such performance unit awards would have been pro-rated based on his number of months of participation in each open Performance Unit Program performance cycle. The amount of the award is based on actual performance achieved, with a stock price set as of the end of the performance period, and payable in the form of a lump sum after the completion of the performance period. For purposes of the table, the value of Mr. McDonald’s awards were calculated as follows: 2010 - 2012 Plan – 667 (1,000 * 24/36) performance units at target, assuming a stock price of $73.05 2011 - 2013 Plan – 400 (1,200 * 12/36) performance units at target, assuming a stock price of $73.05
(4)	In the event of his death, disability or a change in control, all of Mr. McDonald's unvested stock options granted prior to December 30, 2010 would immediately vest. In the event of his death, disability or qualifying termination related to a change in control, all of Mr. McDonald’s unvested stock options granted on or after December 30, 2010 would immediately vest. In addition, he would be entitled to exercise his stock options for the remainder of the ten-year extending from the grant date of the options. For purposes of this table, it is assumed that Mr. McDonald exercised his options immediately upon vesting and received proceeds equal to the difference between the closing price of common stock on December 30, 2011, and the applicable exercise price of each option share. As of December 31, 2011, the closing stock price exceeded the exercise price for Mr. McDonald’s 2011 unvested options and accordingly, such options are reported in the table; all other stock options with respect to the accelerated vesting of Mr. McDonald’s stock options were “underwater” as of December 31, 2011 and are excluded from the table.
(5)	In the event of his death or disability, Mr. McDonald would immediately vest in a pro-rated portion of the unvested restricted stock that was otherwise scheduled to become vested on the immediately following twelve (12)-month grant date anniversary date (as well as dividends declared on the pro-rated portion of such restricted stock). The pro-rated vested portion would be determined based on the number of days between the most recent preceding twelve (12)-month Grant Date anniversary date and the date of his death or Disability. In the event of his qualifying termination related to a change in control, Mr. McDonald would immediately vest in all unvested restricted stock.
(6)	Pursuant to the System Executive Continuity Plan, in the event of a termination related to a change in control, Mr. McDonald would be eligible to receive Entergy-subsidized COBRA benefits for 12 months.

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(7)	As of December 31, 2011, compensation and benefits available to Mr. McDonald under this scenario are substantially the same as available with a voluntary resignation. As of December 31, 2011, Mr. McDonald is not retirement eligible.
(8)	With respect to grants made under the 2007 Equity Ownership Plan prior to December 30, 2010, plan participants are entitled to receive an acceleration of certain benefits based solely upon a change in control of Entergy and without regard to whether their employment is terminated as a result of a change in control. The accelerated benefits in the event of a change in control are as follows: · All unvested stock options would become immediately exercisable; and · Severance benefits in place of performance units become payable as described in footnote 3 above. The 2007 Equity Ownership Plan was amended in December 2010 so that awards granted on or after December 30, 2010 require a qualifying termination in order to accelerate vesting or trigger severance payments.
(9)	In December 2010, the System Executive Continuity Plan was amended to eliminate excise tax gross up payments.

William M. Mohl

President and CEO, Entergy Louisiana

The following table shows certain payments and benefits, excluding vested or earned awards and benefits, which the President and CEO, Entergy Louisiana would have been entitled to receive as a result of a termination of his employment under various scenarios as of December 31, 2011:

Benefits and Payments Upon Termination(1)	Voluntary Resignation	For Cause	Termination for Good Reason or Not for Cause	Retirement(7)	Disability	Death	Change in Control(8)	Termination Related to a Change in Control
Severance Payment(2)	---	---	---	---	---	---	---	$1,006,650
Performance Units:(3)
2010-2012 Performance Unit Program	---	---	---	---	$97,376	$97,376	$146,100	$146,100
2011-2013 Performance Unit Program	---	---	---	---	$60,851	$60,851	---	$127,838
Unvested Stock Options(4)	---	---	---	---	$1,586	$1,586	---	$1,586
Unvested Restricted Stock(5)	---	---	---	---	$26,060	$26,060	---	$84,349
Medical and Dental Benefits(6)	---	---	---	---	---	---	---	$19,124
280G Tax Gross-up(9)	---	---	---	---	---	---	---	---

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(1)	In addition to the payments and benefits in the table, if Mr. Mohl's employment were terminated under certain conditions relating to a change in control, Mr. Mohl also would have been entitled to receive his vested pension benefits and would have been eligible for early retirement benefits. For a description of the pension benefits see "2011 Pension Benefits." If Mr. Mohl's employment were terminated for cause, he would forfeit his benefit under the System Executive Retirement Plan.
(2)	In the event of a qualifying termination related to a change in control, Mr. Mohl would be entitled to receive pursuant to the System Executive Continuity Plan a lump sum severance payment equal to the product of two times the sum of (a) his annual base salary as in effect at any time within one year prior to the commencement of a of a change in control period or, if higher, immediately prior to a circumstance constituting good reason plus (b) his annual incentive, calculated using the average annual target opportunity derived under the Executive Incentive Plan for the two calendar years immediately preceding the calendar year in which the participant’s termination occurs. For purposes of this table, a 50% target opportunity and a base salary of $335,550 was assumed.
(3)	In the event of a change in control (regardless of whether he experienced a qualifying termination), Mr. Mohl would have been entitled, pursuant to the 2007 Equity Ownership Plan, to receive for the 2010-2012 performance period a lump sum payment relating to his performance units. The payment is calculated as if all performance goals relating to the performance units were achieved at target level. For purposes of the table, the value of Mr. Mohl's award was calculated as follows: 2010 - 2012 Plan – 2,000 performance units at target, assuming a stock price of $73.05 In the event of a qualifying termination related to a change in control, Mr. Mohl would have forfeited his performance units for the 2011-2013 performance period and would have been entitled to receive, pursuant to the 2007 Equity Ownership Plan, a single-sum severance payment that would not be based on any outstanding performance periods. For the 2011-2013 performance period, the payment would have been calculated using the average annual number of performance units he would have been entitled to receive under the Performance Unit Program with respect to the two most recent performance periods preceding the calendar year in which his termination occurs, assuming all performance goals were achieved at target. For purposes of the table, the value of Mr. Mohl’s severance payment was calculated by taking an average of the target performance units from the 2007-2009 Performance Unit Program (2,100 units) and the 2008-2010 Performance Unit Program (1,400 units) and multiplying the average number of units (1,750 units) by the closing price of Entergy common stock on December 30, 2011 ($73.05) resulting in a severance payment of $127,838 for the forfeited performance units. In the event of Mr. Mohl’s death or disability not related to a change in control, Mr. Mohl would not have forfeited his performance units for all open performance periods, but rather such performance unit awards would have been pro-rated based on his number of months of participation in each open Performance Unit Program performance cycle. The amount of the award is based on actual performance achieved, with a stock price set as of the end of the performance period, and payable in the form of a lump sum after the completion of the performance period. For purposes of the table, the value of Mr. Mohl's awards were calculated as follows: 2010 - 2012 Plan – 1,333 (2,000 * 24/36) performance units at target, assuming a stock price of $73.05 2011 - 2013 Plan – 833 (2,500 *12/36) performance units at target, assuming a stock price of $73.05

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(4)	In the event of his death, disability or a change in control, all of Mr. Mohl's unvested stock options granted prior to December 30, 2010 would immediately vest. In the event of his death, disability or qualifying termination related to a change in control, all of Mr. Mohl’s unvested stock options granted on or after December 30, 2010 would immediately vest. In addition, he would be entitled to exercise his stock options for the remainder of the ten-year extending from the grant date of the options. For purposes of this table, it is assumed that Mr. Mohl exercised his options immediately upon vesting and received proceeds equal to the difference between the closing price of common stock on December 30, 2011, and the applicable exercise price of each option share. As of December 31, 2011, the closing stock price exceeded the exercise price for Mr. Mohl’s 2011 unvested options and accordingly, such options are reported in the table; all other stock options with respect to the accelerated vesting of Mr. Mohl’s stock options were “underwater” as of December 31, 2011 and are excluded from the table.
(5)	In the event of his death or disability, Mr. Mohl would immediately vest in a pro-rated portion of the unvested restricted stock that was otherwise scheduled to become vested on the immediately following twelve (12)-month grant date anniversary date (as well as dividends declared on the pro-rated portion of such restricted stock). The pro-rated vested portion would be determined based on the number of days between the most recent preceding twelve (12)-month Grant Date anniversary date and the date of his death or Disability. In the event of his qualifying termination related to a change in control, Mr. Mohl would immediately vest in all unvested restricted stock.
(6)	Pursuant to the System Executive Continuity Plan, in the event of a termination related to a change in control, Mr. Mohl would be eligible to receive Entergy-subsidized COBRA benefits for 18 months.
(7)	As of December 31, 2011, compensation and benefits available to Mr. Mohl under this scenario are substantially the same as available with a voluntary resignation. As of December 31, 2011, Mr. Mohl is not retirement eligible.
(8)	With respect to grants made under the 2007 Equity Ownership Plan prior to December 30, 2010, plan participants are entitled to receive an acceleration of certain benefits based solely upon a change in control of Entergy and without regard to whether their employment is terminated as a result of a change in control. The accelerated benefits in the event of a change in control are as follows: · All unvested stock options would become immediately exercisable; and · Severance benefits in place of performance units become payable as described in footnote 3 above. The 2007 Equity Ownership Plan was amended in December 2010 so that awards granted on or after December 30, 2010 require a qualifying involuntary termination in order to accelerate vesting or trigger severance payments.
(9)	In December 2010, the System Executive Continuity Plan was amended to eliminate excise tax gross up payments.

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Charles L. Rice, Jr.

President & CEO - Entergy New Orleans

The following table shows certain payments and benefits, excluding vested or earned awards and benefits, which the President and CEO - Entergy New Orleans would have been entitled to receive as a result of a termination of his employment under various scenarios as of December 31, 2011:

Benefits and Payments Upon Termination(1)	Voluntary Resignation	For Cause	Termination for Good Reason or Not for Cause	Retirement(7)	Disability	Death	Change in Control(8)	Termination Related to a Change in Control
Severance Payment(2)	---	---	---	---	---	---	---	$321,360
Performance Units:(3)
2010-2012 Performance Unit Program	---	---	---	---	$48,724	$48,724	$60,851	$60,851
2011-2013 Performance Unit Program	---	---	---	---	$29,220	$29,220	---	$62,093
Unvested Stock Options(4)	---	---	---	---	$754	$754	---	$754
Unvested Restricted Stock(5)	---	---	---	---	$15,409	$15,409	---	$49,842
Medical and Dental Benefits(6)	---	---	---	---	---	---	---	$888
280G Tax Gross-up(9)	---	---	---	---	---	---	---	---

(1)

In addition to the payments and benefits in the table, if Mr. Rice's employment were terminated under certain conditions relating to a change in control, Mr. Rice also would have been entitled to receive his vested pension benefits and would have been eligible for early retirement benefits. For a description of the pension benefits see "2011 Pension Benefits." If Mr. Rice's employment were terminated for cause, he would forfeit his benefit under the System Executive Retirement Plan.

(2)

In the event of a qualifying termination related to a change in control, Mr. Rice would be entitled to receive pursuant to the System Executive Continuity Plan, a lump sum severance payment equal to the product of one time the sum of (a) his annual base salary as in effect at any time within one year prior to the commencement of a change in control period or, if higher, immediately prior to a circumstance constituting good reason plus (b) his annual incentive, calculated using the average annual target opportunity derived under the Executive Incentive Plan for the two calendar years immediately preceding the calendar year in which the participant’s termination occurs. For purposes of this table, a 30% target opportunity and a base salary of $247,200 was assumed.

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(3)	In the event of a change in control (regardless of whether he experienced a qualifying termination), Mr. Rice would have been entitled to receive pursuant to the 2007 Equity Ownership Plan, to receive for the 2010-2012 performance period a lump sum payment relating to his performance units. The payment is calculated as if all performance goals relating to the performance units were achieved at target level. For purposes of the table, the value of Mr. Rice’s award was calculated as follows: 2010 - 2012 Plan – 833 performance units at target, assuming a stock price of $73.05 In the event of a qualifying termination related to a change in control, Mr. Rice would have forfeited his performance units for the 2011-2013 performance period and would have been entitled to receive, pursuant to the 2007 Equity Ownership Plan, a single-sum severance payment that would not be based on any outstanding performance periods. For the 2011-2013 performance period, the payment would have been calculated using the average annual number of performance units he would have been entitled to receive under the Performance Unit Program with respect to the two most recent performance periods preceding the calendar year in which his termination occurs, assuming all performance goals were achieved at target. For purposes of the table, the value of Mr. Rice’s severance payment was calculated by taking an average of the target performance units from the 2007-2009 Performance Unit Program (1,000 units) and the 2008-2010 Performance Unit Program (700 units) and multiplying the average number of units (850 units) by the closing price of Entergy common stock on December 30, 2011 ($73.05) resulting in a severance payment of $ $62,093 for the forfeited performance units. In the event of Mr. Rice’s death or disability not related to a change in control, Mr. Rice would not have forfeited his performance units for all open performance periods, but rather such performance unit awards would have been pro-rated based on his number of months of participation in each open Performance Unit Program performance cycle. The amount of the award is based on actual performance achieved, with a stock price set as of the end of the performance period, and payable in the form of a lump sum after the completion of the performance period. For purposes of the table, the value of Mr. Rice’s awards were calculated as follows: 2010 - 2012 Plan – 555 (833 * 24/36) performance units at target, assuming a stock price of $73.05 2011 - 2013 Plan – 400 (1,200 * 12/36) performance units at target, assuming a stock price of $73.05
(4)	In the event of his death, disability or a change in control, all of Mr. Rice's unvested stock options granted prior to December 30, 2010 would immediately vest. In the event of his death, disability or qualifying termination related to a change in control, all of Mr. Rice’s unvested stock options granted on or after December 30, 2010 would immediately vest. In addition, he would be entitled to exercise his stock options for the remainder of the ten-year extending from the grant date of the options. For purposes of this table, it is assumed that Mr. Rice exercised his options immediately upon vesting and received proceeds equal to the difference between the closing price of common stock on December 30, 2011, and the applicable exercise price of each option share. As of December 31, 2011, the closing stock price exceeded the exercise price for Mr. Rice’s 2011 unvested options and such options are reported in the table. Mr. Rice has no other unvested stock options prior to 2011.
(5)	In the event of his death or disability, Mr. Rice would immediately vest in a pro-rated portion of the unvested restricted stock that was otherwise scheduled to become vested on the immediately following twelve (12)-month grant date anniversary date (as well as dividends declared on the pro-rated portion of such restricted stock). The pro-rated vested portion would be determined based on the number of days between the most recent preceding twelve (12)-month Grant Date anniversary date and the date of his death or Disability. In the event of his qualifying termination related to a change in control, Mr. Rice would immediately vest in all unvested restricted stock.
(6)	Pursuant to the System Executive Continuity Plan, in the event of a termination related to a change in control, Mr. Rice would be eligible to receive Entergy-subsidized COBRA benefits for 12 months.
(7)	As of December 31, 2011, compensation and benefits available to Mr. Rice under this scenario are substantially the same as available with a voluntary resignation. As of December 31, 2011, Mr. Rice is not retirement eligible.

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(8)

With respect to grants made under the 2007 Equity Ownership Plan prior to December 30, 2010, plan participants are entitled to receive an acceleration of certain benefits based solely upon a change in control of Entergy and without regard to whether their employment is terminated as a result of a change in control. The accelerated benefits in the event of a change in control are as follows:

· All unvested stock options would become immediately exercisable; and

· Severance benefits in place of performance units become payable as described in footnote 3 above.

The 2007 Equity Ownership Plan was amended in December 2010 so that awards granted on or after December 30, 2010 require a qualifying involuntary termination in order to accelerate vesting or trigger severance payments.

(9)

In December 2010, the System Executive Continuity Plan was amended to eliminate excise tax gross up payments.

Gary J. Taylor

Group President, Utility Operations

The following table shows certain payments and benefits, excluding vested or earned awards and benefits, which the Group President, Utility Operations would have been entitled to receive as a result of a termination of his employment under various scenarios as of December 31, 2011:

Benefits and Payments Upon Termination(1)	Voluntary Resignation	For Cause	Termination for Good Reason or Not for Cause	Retirement(7)	Disability	Death	Change in Control(8)	Termination Related to a Change in Control
Benefits and Payments Upon Termination(1)	Voluntary Resignation	For Cause	Termination for Good Reason or Not for Cause	Retirement(7)	Disability	Death	Change in Control(8)	Termination Related to a Change in Control

Severance Payment(2)	---	---	---	---	---	---	---	$3,013,202
Performance Units:(3)
2010-2012 Performance Unit Program	---	---	---	$258,086	$258,086	$258,086	$387,165	$387,165
2011-2013 Performance Unit Program	---	---	---	$143,689	$143,689	$143,689	---	$306,810
Unvested Stock Options(4)	---	---	---	$5,200	$5,200	$5,200	---	$5,200
Unvested Restricted Stock(5)	---	---	---	---	$71,008	$71,008	---	$230,041

Medical and Dental Benefits(6)	---	---	---	---	---	---	---	---
280G Tax Gross-up(9)	---	---	---	---	---	---	---	---

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(1)	In addition to the payments and benefits in the table, Mr. Taylor would have been eligible to retire and entitled to receive his vested pension benefits. For a description of the pension benefits available to Named Executive Officers, see “2011 Pension Benefits.” In the event of a termination related to a change in control, pursuant to the terms of the System Executive Retirement Plan, Mr. Taylor would be eligible for subsidized early retirement even if he does not have company permission to separate from employment. If Mr. Taylor’s employment were terminated for cause, he would not receive a benefit under the System Executive Retirement Plan.
(2)	In the event of a qualifying termination related to a change in control, Mr. Taylor would be entitled to receive pursuant to the System Executive Continuity Plan a lump sum severance payment equal to the product of 2.99 times the sum of (a) his annual base salary as in effect at any time within one year prior to the commencement of a change in control period or, if higher, immediately prior to a circumstance constituting good reason plus (b) his annual incentive, calculated using the average annual target opportunity derived under the Annual Incentive Plan for the two calendar years immediately preceding the calendar year in which the participant’s termination occurs. For purposes of this table, a 70% target opportunity and a base salary of $592,800 was assumed.
(3)	In the event of a change in control (regardless of whether he experienced a qualifying termination), Mr. Taylor would have been entitled, pursuant to the 2007 Equity Ownership Plan, to receive for the 2010-2012 performance period a lump sum payment relating to his performance units. The payment is calculated as if all performance goals relating to the performance units were achieved at target level. For purposes of the table, the value of Mr. Taylor's award was calculated as follows: 2010 - 2012 Plan – 5,300 performance units at target, assuming a stock price of $73.05 In the event of a qualifying termination related to a change in control, Mr. Taylor would have forfeited his performance units for the 2011-2013 performance period and would have been entitled to receive, pursuant to the 2007 Equity Ownership Plan, a single-sum severance payment that would not be based on any outstanding performance periods. For the 2011-2013 performance period, the payment would have been calculated using the average annual number of performance units he would have been entitled to receive under the Performance Unit Program with respect to the two most recent performance periods preceding the calendar year in which his termination occurs, assuming all performance goals were achieved at target. For purposes of the table, the value of Mr. Taylor’s severance payment was calculated by taking an average of the target performance units from the 2007-2009 Performance Unit Program (4,500 units) and the 2008-2010 Performance Unit Program (3,900 units) and multiplying the average number of units (4,200 units) by the closing price of Entergy common stock on December 30, 2011 ($73.05) resulting in a severance payment of $306,810 for the forfeited performance units. In the event of Mr. Taylor’s death, disability or retirement not related to a change in control, Mr. Taylor would not have forfeited his performance units for all open performance periods, but rather such performance unit awards would have been pro-rated based on his number of months of participation in each open Performance Unit Program performance cycle. The amount of the award is based on actual performance achieved, with a stock price set as of the end of the performance period, and payable in the form of a lump sum after the completion of the performance period. For purposes of the table, the value of Mr. Taylor's awards were calculated as follows: 2010 - 2012 Plan – 3,533 (5,300 * 24/36) performance units at target, assuming a stock price of $73.05 2011 - 2013 Plan – 1,967 (5,900 * 12/36) performance units at target, assuming a stock price of $73.05
(4)	In the event of his retirement, death, disability or a change in control, all of Mr. Taylor’s unvested stock options granted prior to December 31, 2010 would immediately vest. In the event of his retirement, death, disability or qualifying termination related to a change in control, all of Mr. Taylor’s unvested stock options granted on or after December 30, 2010 would immediately vest. In addition, he would be entitled to exercise his stock options for a ten-year term extending from the grant date of the options. For purposes of this table, it was assumed that Mr. Taylor exercised his options immediately upon vesting and received proceeds equal to the difference between the closing price of common stock on December 30, 2011, and the exercise price of each option share. As of December 31, 2011, the closing stock price exceeded the exercise price for Mr. Taylor’s 2011 unvested options and accordingly, such options are reported in the table; all other stock options with respect to the accelerated vesting of Mr. Taylor’s stock options were “underwater” as of December 31, 2011 and are excluded from the table.

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(5)	In the event of his death or disability, Mr. Taylor would immediately vest in a pro-rated portion of the unvested restricted stock that was otherwise scheduled to become vested on the immediately following twelve (12)-month grant date anniversary date (as well as dividends declared on the pro-rated portion of such restricted stock). The pro-rated vested portion would be determined based on the number of days between the most recent preceding twelve (12)-month Grant Date anniversary date and the date of his death or Disability. In the event of his qualifying termination related to a change in control, Mr. Taylor would immediately vest in all unvested restricted stock.
(6)	Upon retirement, Mr. Taylor would be eligible for retiree medical and dental benefits at the same level as all other retirees. Pursuant to the System Executive Continuity Plan, in the event of a termination related to a change in control, Mr. Taylor would not be eligible to receive Entergy-subsidized COBRA benefits.
(7)	As of December 31, 2011, Mr. Taylor is retirement eligible and would retire rather than voluntarily resign. Given that scenario, the compensation and benefits available to Mr. Taylor under retirement are substantially the same as available with a voluntary resignation. Mr. Taylor has advised Entergy that he intends to resign from his position as Group President, Utility Operations, effective May 31, 2012.
(8)	With respect to grants made under the 2007 Equity Ownership Plan prior to December 30, 2010, plan participants are entitled to receive an acceleration of certain benefits based solely upon a change in control of Entergy and without regard to whether their employment is terminated as a result of a change in control. The accelerated benefits in the event of a change in control are as follows: · All unvested stock options would become immediately exercisable; and · Severance benefits in place of performance units become payable as described in footnote 3 above. The 2007 Equity Ownership Plan was amended in December 2010 so that awards granted on or after December 30, 2010 require a qualifying involuntary termination in order to accelerate vesting or trigger severance payments.
(9)	In December 2010, the System Executive Continuity Plan was amended to eliminate excise tax gross up payments.

In the following sections, additional information is provided regarding certain of the scenarios described in the tables above:

Termination Related to a Change in Control

Under the System Executive Continuity Plan, the Named Executive Officers will be entitled to the benefits described in the tables above in the event of a termination related to a change in control if their employment is terminated other than for cause or if they terminate their employment for good reason, in each case within a period commencing 90 days prior to and ending 24 months following a change in control.

A change in control includes the following events:

·	The purchase of 30% or more of either the common stock or the combined voting power of the voting securities, the merger or consolidation of Entergy Corporation (unless Entergy Corporation's board members constitute at least a majority of the board members of the surviving entity);

·	the merger or consolidation of Entergy Corporation (unless Entergy Corporation's board members constitute at least a majority of the board members of the surviving entity);

·	the liquidation, dissolution or sale of all or substantially all of Entergy Corporation's assets; or

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·	a change in the composition of Entergy Corporation's board such that, during any two-year period, the individuals serving at the beginning of the period no longer constitute a majority of Entergy Corporation's board at the end of the period.

The proposed separation of the non-utility nuclear business in a tax-free spin-off to Entergy Corporation's shareholders does not constitute a "Change in Control" for purposes of the System Executive Continuity Plan.

Entergy Corporation may terminate a Named Executive Officer's employment for cause under the System Executive Continuity Plan if he or she:

·	fails to substantially perform his duties for a period of 30 days after receiving notice from the board;

·	engages in conduct that is injurious to Entergy Corporation or any of its subsidiaries;

·	is convicted or pleads guilty to a felony or other crime that materially and adversely affects his or her ability to perform his or her duties or Entergy Corporation's reputation;

·	violates any agreement with Entergy Corporation or any of its subsidiaries; or

·	discloses any of Entergy Corporation's confidential information without authorization.

A Named Executive Officer may terminate employment with Entergy Corporation for good reason under the System Executive Continuity Plan if, without the Named Executive Officer's consent:

·	the nature or status of his or her duties and responsibilities is substantially altered or reduced compared to the period prior to the change in control;

·	his or her salary is reduced by 5% or more;

·	he or she is required to be based outside of the continental United States at somewhere other than the primary work location prior to the change in control;

·	any of his or her compensation plans are discontinued without an equitable replacement;

·	his or her benefits or number of vacation days are substantially reduced; or

·	his or her employment is purported to be terminated other than in accordance with the System Executive Continuity Plan.

In addition to participation in the System Executive Continuity Plan, upon the completion of a transaction resulting in a change in control of Entergy Corporation, benefits already accrued under the System Executive Retirement Plan and Pension Equalization Plan, if any, will become fully vested if the executive is involuntarily terminated without cause or terminates employment for good reason. Any awards granted under the Equity Ownership Plan will become fully vested upon a Change in Control without regard to whether the executive is involuntarily terminated without cause or terminates employment for good reason.

Under certain circumstances, the payments and benefits received by a Named Executive Officer pursuant to the System Executive Continuity Plan may be forfeited and, in certain cases, subject to repayment. Benefits are no longer payable under the System Executive Continuity Plan, and unvested performance units under the Performance Unit Program are subject to forfeiture, if the executive:

·	accepts employment with Entergy Corporation or any of its subsidiaries;

·	elects to receive the benefits of another severance or separation program;

·	removes, copies or fails to return any property belonging to Entergy Corporation or any of its subsidiaries;

·	discloses non-public data or information concerning Entergy Corporation or any of its subsidiaries; or

·	violates their non-competition provision, which generally runs for two years but extends to three years if permissible under applicable law.

Furthermore, if the executive discloses non-public data or information concerning Entergy Corporation or any of its subsidiaries or violates their non-competition provision, he or she will be required to repay any benefits previously received under the System Executive Continuity Plan.

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Termination for Cause

If a Named Executive Officer's employment is terminated for "cause" (as defined in the System Executive Continuity Plans and described above under "Termination Related to a Change in Control"), he or she is generally entitled to the same compensation and separation benefits described below under "Voluntary Resignation" except that all options may no longer be exercisable.

Voluntary Resignation

If a Named Executive Officer voluntarily resigns from an Entergy System company employer, he or she is entitled to all accrued benefits and compensation as of the separation date, including qualified pension benefits (if any) and other post-employment benefits on terms consistent with those generally available to other salaried employees. In the case of voluntary resignation, the officer would forfeit all unvested stock options and restricted units as well as any perquisites to which he or she is entitled as an officer. In addition, the officer would forfeit, except as described below, his or her right to receive incentive payments under the Performance Unit Program or the Executive Incentive Plan. If the officer resigns after the completion of an Executive Incentive Plan or Performance Unit Program performance period, he or she could receive a payout under the Performance Unit Program based on the outcome of the performance cycle and could, at the Entergy Corporation's discretion, receive an annual incentive payment under the Executive Incentive Plan. Any vested stock options held by the officer as of the separation date will expire the earlier of ten years from date of grant or 90 days from the last day of active employment.

Retirement

Under Entergy Corporation's retirement plans, a Named Executive Officer's eligibility for retirement benefits is based on a combination of age and years of service. Normal retirement is defined as age 65. Early retirement is defined under the qualified retirement plan as minimum age 55 with 10 years of service and in the case of the System Executive Retirement Plan and the supplemental credited service under the Pension Equalization Plan, the consent of Entergy System company employer.

Upon a Named Executive Officer's retirement, he or she is generally entitled to all accrued benefits and compensation as of the separation date, including qualified pension benefits and other post-employment benefits consistent with those generally available to salaried employees. The annual incentive payment under the Executive Incentive Plan is pro-rated based on the actual number of days employed during the performance year in which the retirement date occurs. Similarly, payments under the Performance Unit Program for those retiring with a minimum of 12 months of participation are pro-rated based on the actual number of days employed, in each outstanding performance cycle, in which the retirement date occurs. In each case, payments are delivered at the conclusion of each annual or performance cycle, consistent with the timing of payments to active participants in the Executive Incentive Plan and the Performance Unit Program, respectively.

Unvested stock options issued under the Equity Ownership Plan vest on the retirement date and expire ten years from the grant date of the options. Any restricted units held (other than those issued under the Performance Unit Program) by the executive upon his or her retirement are forfeited, and perquisites (other than short-term financial counseling services) are not available following the separation date.

Disability

If a Named Executive Officer's employment is terminated due to disability, he or she generally is entitled to the same compensation and separation benefits described above under "Retirement," except that restricted units may be subject to specific disability benefits (as noted, where applicable, in the tables above).

Death

If a Named Executive Officer dies while actively employed by an Entergy System company employer, he or she generally is entitled to the same compensation and separation benefits described above under "Retirement," except that:

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·	all unvested stock options granted prior to January 1, 2007 are forfeited;

·	vested stock options will expire the earlier of ten years from the grant date or three years following the executive's death;

·	restricted units may be subject to specific death benefits (as noted, where applicable, in the tables above).

Compensation of Directors

For information regarding compensation of the directors of Entergy Corporation, see the Proxy Statement under the heading “Director Compensation”, which information is incorporated herein by reference. The Boards of Directors of Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans and Entergy Texas are comprised solely of employee directors who receive no compensation for service as directors.

Item 12. Security Ownership of Certain Beneficial Owners and Management

Entergy Corporation owns 100% of the outstanding common stock of registrants Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans and Entergy Texas. The information with respect to persons known by Entergy Corporation to be beneficial owners of more than 5% of Entergy Corporation’s outstanding common stock is included under the heading “Stockholders Who Own at Least Five Percent” in the Proxy Statement, which information is incorporated herein by reference. The registrants know of no contractual arrangements that may, at a subsequent date, result in a change in control of any of the registrants.

The following table sets forth the beneficial ownership of Common Stock of Entergy Corporation and stock-based units as of December 31, 2011 for all directors and Named Executive Officers. Unless otherwise noted, each person had sole voting and investment power over the number of shares of Common Stock and stock-based units of Entergy Corporation set forth across from his or her name.

Name	Shares (1)	Options Exercisable Within 60 Days	Stock Units (2)

Entergy Corporation
Maureen S. Bateman*	4,300	-	8,800
Leo P. Denault**	14,126	334,294	-
Gary W. Edwards*	1,400	-	7,181
Alexis Herman*	5,118	-	6,400
Donald C. Hintz*	8,944	260,000	6,950
J. Wayne Leonard***	444,898	1,458,533	3,111
Stuart L. Levenick*	3,800	-	4,631
Blanche L. Lincoln*	454	-	200
Stewart C. Myers*	1,376	-	1,383
William A. Percy, II*	3,100	-	13,104
Mark T. Savoff**	4,363	199,467	263
Richard J. Smith**	45,672	365,933	-
W. J. Tauzin*	3,700	-	4,493
Gary J. Taylor**	4,674	310,233	-
Steven V. Wilkinson*	4,855	-	6,027
All directors and executive
officers as a group (21 persons)	585,170	3,497,111	62,543

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Name	Shares (1)	Options Exercisable Within 60 Days	Stock Units (2)

Entergy Arkansas
Theodore H. Bunting, Jr.**	2,818	60,133	-
Leo P. Denault***	14,126	334,294	-
J. Wayne Leonard**	444,898	1,458,533	3,111
Hugh T. McDonald***	10,091	67,555	-
Mark T. Savoff*	4,363	199,467	263
Gary J. Taylor***	4,674	310,233	-
All directors and executive
officers as a group (12 persons)	558,214	3,304,666	3,374

Entergy Gulf States Louisiana
Theodore H. Bunting, Jr.**	2,818	60,133	-
Leo P. Denault***	14,126	334,294	-
J. Wayne Leonard**	444,898	1,458,533	3,111
William M. Mohl***	1,154	36,333	-
Mark T. Savoff*	4,363	199,467	263
Gary J. Taylor***	4,674	310,233	-
All directors and executive
officers as a group (12 persons)	549,277	3,273,444	3,374

Entergy Louisiana
Theodore H. Bunting, Jr.**	2,818	60,133	-
Leo P. Denault***	14,126	334,294	-
J. Wayne Leonard**	444,898	1,458,533	3,111
William M. Mohl***	1,154	36,333	-
Mark T. Savoff*	4,363	199,467	263
Gary J. Taylor***	4,674	310,233	-
All directors and executive
officers as a group (12 persons)	549,277	3,273,444	3,374

Entergy Mississippi
Theodore H. Bunting, Jr.**	2,818	60,133	-
Leo P. Denault***	14,126	334,294	-
Haley R. Fisackerly***	2,743	19,267	-
J. Wayne Leonard**	444,898	1,458,533	3,111
Mark T. Savoff*	4,363	199,467	263
Gary J. Taylor***	4,674	310,233	-
All directors and executive
officers as a group (12 persons)	550,866	3,256,378	3,374

Entergy New Orleans
Theodore H. Bunting, Jr.**	2,818	60,133	-
Leo P. Denault***	14,126	334,294	-
J. Wayne Leonard**	444,898	1,458,533	3,111
Charles L. Rice, Jr.***	1,253	967	-
Mark T. Savoff*	4,363	199,467	263
Gary J. Taylor***	4,674	310,233	-
All directors and executive
officers as a group (12 persons)	549,376	3,238,078	3,374

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Name	Shares (1)	Options Exercisable Within 60 Days	Stock Units (2)

Entergy Texas
Theodore H. Bunting, Jr.**	2,818	60,133	-
Leo P. Denault***	14,126	334,294	-
Joseph F. Domino***	954	65,533	-
J. Wayne Leonard**	444,898	1,458,533	3,111
Mark T. Savoff*	4,363	199,467	263
Gary J. Taylor***	4,674	310,233	-
All directors and executive
officers as a group (12 persons)	549,077	3,302,644	3,374

*	Director of the respective Company
**	Named Executive Officer of the respective Company
***	Director and Named Executive Officer of the respective Company

(1)

The number of shares of Entergy Corporation common stock owned by each individual and by all directors and executive officers as a group does not exceed one percent of the outstanding Entergy Corporation common stock.

(2)

Represents the balances of phantom units each executive holds under the defined contribution restoration plan and the deferral provisions of the Equity Ownership Plan. These units will be paid out in either Entergy Corporation Common Stock or cash equivalent to the value of one share of Entergy Corporation Common Stock per unit on the date of payout, including accrued dividends. The deferral period is determined by the individual and is at least two years from the award of the bonus. For directors of Entergy Corporation the phantom units are issued under the Service Recognition Program for Outside Directors. All non-employee directors are credited with units for each year of service on the Board. In addition, Messrs. Edwards, Hintz and Percy have deferred receipt of some of their quarterly stock grants. The deferred shares will be settled in units at the end of the deferral period.

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Equity Compensation Plan Information

The following table summarizes the equity compensation plan information as of December 31, 2011. Information is included for equity compensation plans approved by the stockholders and equity compensation plans not approved by the stockholders.

Plan	Number of Securities to be Issued Upon Exercise of Outstanding Options (a)	Weighted Average Exercise Price (b)	Number of Securities Remaining Available for Future Issuance (excluding securities reflected in column (a)) (c)

Equity compensation plans approved by security holders (1)	9,683,058	$78.07	7,269,562
Equity compensation plans not approved by security holders(2)	776,360	$42.82	-
Total	10,459,418	$75.46	7,269,562

(1)

Includes the Equity Ownership Plan, which was approved by the shareholders on May 15, 1998, the 2007 Equity Ownership Plan and the 2011 Equity Ownership Plan. The 2007 Equity Ownership Plan was approved by Entergy Corporation shareholders on May 12, 2006, and 7,000,000 shares of Entergy Corporation common stock can be issued, with no more than 2,000,000 shares available for non-option grants. The 2011 Equity Ownership Plan was approved by Entergy Corporation shareholders on May 6, 2011, and 5,500,000 shares of Entergy Corporation common stock can be issued from the 2011 Equity Ownership Plan, with no more than 2,000,000 shares available for incentive stock option grants. The Equity Ownership Plan, the 2007 Equity Ownership Plan and the 2011 Equity Ownership Plan (the “Plans”) are administered by the Personnel Committee of the Board of Directors (other than with respect to awards granted to non-employee directors, which awards are administered by the entire Board of Directors). Eligibility under the Plans is limited to the non-employee directors and to the officers and employees of an Entergy System employer and any corporation 80% or more of whose stock (based on voting power) or value is owned, directly or indirectly, by Entergy Corporation. The Plans provide for the issuance of stock options, restricted shares, equity awards (units whose value is related to the value of shares of the Common Stock but do not represent actual shares of Common Stock), performance awards (performance shares or units valued by reference to shares of Common Stock or performance units valued by reference to financial measures or property other than Common Stock) and other stock-based awards.

(2)

Entergy has a Board-approved stock-based compensation plan. However, effective May 9, 2003, the Board has directed that no further awards be issued under that plan.

Item 13. Certain Relationships and Related Transactions and Director Independence

For information regarding certain relationships, related transactions and director independence of Entergy Corporation, see the Proxy Statement under the headings “Corporate Governance - Director Independence” and “Transactions with Related Persons,” which information is incorporated herein by reference.

Since December 31, 2010, none of the Subsidiaries or any of their affiliates has participated in any transaction involving an amount in excess of $120,000 in which any director or executive officer of any of the Subsidiaries, any nominee for director, or any immediate family member of the foregoing had a material interest as contemplated by Item 404(a) of Regulation S-K (“Related Party Transactions”).

Entergy Corporation’s Board of Directors has adopted written policies and procedures for the review, approval or ratification of Related Party Transactions. Under these policies and procedures, the Corporate Governance Committee, or a subcommittee of the Board of Directors of Entergy Corporation composed of independent directors, reviews the transaction and either approves or rejects the transaction after taking into account the following factors:

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·	Whether the proposed transaction is on terms at least as favorable to Entergy Corporation or the subsidiary as those achievable with an unaffiliated third party;

·	Size of transaction and amount of consideration;

·	Nature of the interest;

·	Whether the transaction involves a conflict of interest;

·	Whether the transaction involves services available from unaffiliated third parties; and

·	Any other factors that the Corporate Governance Committee or subcommittee deems relevant.

The policy does not apply to (a) compensation and Related Party Transactions involving a director or an executive officer solely resulting from that person’s service as a director or employment with the Company so long as the compensation is approved by Entergy’s Board of Directors, (b) transactions involving the rendering of services as a public utility at rates or charges fixed in conformity with law or governmental authority or (c) any other categories of transactions currently or in the future excluded from the reporting requirements of Item 404(a) of Regulation SK.

None of the Subsidiaries are listed issuers. As previously noted, the Boards of Directors of the Subsidiaries are composed solely of employee directors. None of the Boards of Directors of any of the Subsidiaries has any committees.

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Item 14. Principal Accountant Fees and Services (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Aggregate fees billed to Entergy Corporation (consolidated), Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy for the years ended December 31, 2011 and 2010 by Deloitte & Touche LLP, were as follows:

	2011	2010
Entergy Corporation (consolidated)
Audit Fees	$9,096,870	$8,376,900
Audit-Related Fees (a)	740,000	1,235,000

Total audit and audit-related fees	9,836,870	9,611,900
Tax Fees (b)	46,083	43,812
All Other Fees	-	-

Total Fees (c)	$9,882,953	$9,655,712

Entergy Arkansas
Audit Fees	$969,218	$956,592
Audit-Related Fees (a)	-	200,000

Total audit and audit-related fees	969,218	1,156,592
Tax Fees	-	-
All Other Fees	-	-

Total Fees (c)	$969,218	$1,156,592

Entergy Gulf States Louisiana
Audit Fees	$897,218	$876,592
Audit-Related Fees (a)	80,000	315,000

Total audit and audit-related fees	977,218	1,191,592
Tax Fees	-	-
All Other Fees	-	-

Total Fees (c)	$977,218	$1,191,592

Entergy Louisiana
Audit Fees	$1,031,718	$946,592
Audit-Related Fees (a)	280,000	315,000

Total audit and audit-related fees	1,311,718	1,261,592
Tax Fees	-	-
All Other Fees	-	-

Total Fees (c)	$1,311,718	$1,261,592

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	2011	2010
Entergy Mississippi
Audit Fees	$971,218	$838,092
Audit-Related Fees (a)	-	-

Total audit and audit-related fees	971,218	838,092
Tax Fees	-	-
All Other Fees	-	-

Total Fees (c)	$971,218	$838,092

Entergy New Orleans
Audit Fees	$901,218	$838,092
Audit-Related Fees (a)	-	-

Total audit and audit-related fees	901,218	838,092
Tax Fees	-	-
All Other Fees	-	-

Total Fees (c)	$901,218	$838,092

Entergy Texas
Audit Fees	$1,945,188	$998,092
Audit-Related Fees (a)	-	-

Total audit and audit-related fees	1,945,188	998,092
Tax Fees	-	-
All Other Fees	-	-

Total Fees (c)	$1,945,188	$998,092

System Energy
Audit Fees	$901,218	$803,092
Audit-Related Fees (a)	-	-

Total audit and audit-related fees	901,218	803,092
Tax Fees	-	-
All Other Fees	-	-

Total Fees (c)	$901,218	$803,092

(a)	Includes fees for employee benefit plan audits, consultation on financial accounting and reporting, and other attestation services.
(b)	Includes fees for tax advisory services.
(c)	100% of fees paid in 2011 and 2010 were pre-approved by the Entergy Corporation Audit Committee.

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Entergy Audit Committee Guidelines for Pre-approval of Independent Auditor Services

The Audit Committee has adopted the following guidelines regarding the engagement of Entergy’s independent auditor to perform services for Entergy:

1.	The independent auditor will provide the Audit Committee, for approval, an annual engagement letter outlining the scope of services proposed to be performed during the fiscal year, including audit services and other permissible non-audit services (e.g. audit-related services, tax services, and all other services).
2.	For other permissible services not included in the engagement letter, Entergy management will submit a description of the proposed service, including a budget estimate, to the Audit Committee for pre-approval. Management and the independent auditor must agree that the requested service is consistent with the SEC’s rules on auditor independence prior to submission to the Audit Committee. The Audit Committee, at its discretion, will pre-approve permissible services and has established the following additional guidelines for permissible non-audit services provided by the independent auditor: · Aggregate non-audit service fees are targeted at fifty percent or less of the approved audit service fee. · All other services should only be provided by the independent auditor if it is the only qualified provider of that service or if the Audit Committee specifically requests the service.
3.	The Audit Committee will be informed quarterly as to the status of pre-approved services actually provided by the independent auditor.
4.	To ensure prompt handling of unexpected matters, the Audit Committee delegates to the Audit Committee Chair or its designee the authority to approve permissible services and fees. The Audit Committee Chair or designee will report action taken to the Audit Committee at the next scheduled Audit Committee meeting.
5.	The Vice President and General Auditor will be responsible for tracking all independent auditor fees and will report quarterly to the Audit Committee.

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PART IV

Item 15. Exhibits and Financial Statement Schedules

(a)1.	Financial Statements and Independent Auditors’ Reports for Entergy, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are listed in the Table of Contents.

(a)2.	Financial Statement Schedules Report of Independent Registered Public Accounting Firm (see page 494) Financial Statement Schedules are listed in the Index to Financial Statement Schedules (see page S-1)

(a)3.	Exhibits Exhibits for Entergy, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are listed in the Exhibit Index (see page E-1). Each management contract or compensatory plan or arrangement required to be filed as an exhibit hereto is identified as such by footnote in the Exhibit Index.

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ENTERGY CORPORATION

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.

ENTERGY CORPORATION

By /s/ Theodore H. Bunting, Jr.

Theodore H. Bunting, Jr.

Senior Vice President and Chief Accounting Officer

Date: February 27, 2012

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated. The signature of each of the undersigned shall be deemed to relate only to matters having reference to the above-named company and any subsidiaries thereof.

Signature	Title	Date


/s/ Theodore H. Bunting, Jr. Theodore H. Bunting, Jr.	Senior Vice President and Chief Accounting Officer (Principal Accounting Officer)	February 27, 2012

J. Wayne Leonard (Chairman of the Board, Chief Executive Officer and Director; Principal Executive Officer); Leo P. Denault (Executive Vice President and Chief Financial Officer; Principal Financial Officer); Maureen S. Bateman, Gary W. Edwards, Alexis M. Herman, Donald C. Hintz, Stuart L. Levenick, Blanche L. Lincoln, Stewart C. Myers, William A. Percy, II, W. J. Tauzin, and Steven V. Wilkinson (Directors).

By: /s/ Theodore H. Bunting, Jr. (Theodore H. Bunting, Jr., Attorney-in-fact)	February 27, 2012

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ENTERGY ARKANSAS, INC.

SIGNATURES

ENTERGY ARKANSAS, INC.

By /s/ Theodore H. Bunting, Jr.

Theodore H. Bunting, Jr.

Senior Vice President and Chief Accounting Officer

Date: February 27, 2012

Signature	Title	Date


/s/ Theodore H. Bunting, Jr. Theodore H. Bunting, Jr.	Senior Vice President and Chief Accounting Officer (Principal Accounting Officer and acting Principal Financial Officer)	February 27, 2012

Hugh T. McDonald (Chairman of the Board, President, Chief Executive Officer, and Director; Principal Executive Officer); Leo P. Denault, Mark T. Savoff, and Gary J. Taylor (Directors).

By: /s/ Theodore H. Bunting, Jr.

(Theodore H. Bunting, Jr., Attorney-in-fact)

February 27, 2012

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ENTERGY GULF STATES LOUISIANA, L.L.C.

SIGNATURES

ENTERGY GULF STATES LOUISIANA, L.L.C.

By /s/ Theodore H. Bunting, Jr.

Theodore H. Bunting, Jr.

Senior Vice President and Chief Accounting Officer

Date: February 27, 2012

Signature	Title	Date


/s/ Theodore H. Bunting, Jr. Theodore H. Bunting, Jr.	Senior Vice President and Chief Accounting Officer (Principal Accounting Officer and acting Principal Financial Officer)	February 27, 2012

William M. Mohl (Chairman of the Board, President, Chief Executive Officer, and Director; Principal Executive Officer); Leo P. Denault, Mark T. Savoff, and Gary J. Taylor (Directors).

By: /s/ Theodore H. Bunting, Jr.

(Theodore H. Bunting, Jr., Attorney-in-fact)

February 27, 2012

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ENTERGY LOUISIANA, LLC

SIGNATURES

ENTERGY LOUISIANA, LLC

By /s/ Theodore H. Bunting, Jr.

Theodore H. Bunting, Jr.

Senior Vice President and Chief Accounting Officer

Date: February 27, 2012

Signature	Title	Date


/s/ Theodore H. Bunting, Jr. Theodore H. Bunting, Jr.	Senior Vice President and Chief Accounting Officer (Principal Accounting Officer and acting Principal Financial Officer)	February 27, 2012

William M. Mohl (Chairman of the Board, President, Chief Executive Officer, and Director; Principal Executive Officer); Leo P. Denault, Mark T. Savoff, and Gary J. Taylor (Directors).

By: /s/ Theodore H. Bunting, Jr.

(Theodore H. Bunting, Jr., Attorney-in-fact)

February 27, 2012

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ENTERGY MISSISSIPPI, INC.

SIGNATURES

ENTERGY MISSISSIPPI, INC.

By /s/ Theodore H. Bunting, Jr.

Theodore H. Bunting, Jr.

Senior Vice President and Chief Accounting Officer

Date: February 27, 2012

Signature	Title	Date


/s/ Theodore H. Bunting, Jr. Theodore H. Bunting, Jr.	Senior Vice President and Chief Accounting Officer (Principal Accounting Officer and acting Principal Financial Officer)	February 27, 2012

Haley R. Fisackerly (Chairman of the Board, President, Chief Executive Officer, and Director; Principal Executive Officer); Leo P. Denault, Mark T. Savoff, and Gary J. Taylor (Directors).

By: /s/ Theodore H. Bunting, Jr.

(Theodore H. Bunting, Jr., Attorney-in-fact)

February 27, 2012

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ENTERGY NEW ORLEANS, INC.

SIGNATURES

ENTERGY NEW ORLEANS, INC.

By /s/ Theodore H. Bunting, Jr.

Theodore H. Bunting, Jr.

Senior Vice President and Chief Accounting Officer

Date: February 27, 2012

Signature	Title	Date


/s/ Theodore H. Bunting, Jr. Theodore H. Bunting, Jr.	Senior Vice President and Chief Accounting Officer (Principal Accounting Officer and acting Principal Financial Officer)	February 27, 2012

Charles L. Rice, Jr. (Chairman of the Board, President, Chief Executive Officer, and Director; Principal Executive Officer); Leo P. Denault, Mark T. Savoff, and Gary J. Taylor (Directors).

By: /s/ Theodore H. Bunting, Jr.

(Theodore H. Bunting, Jr., Attorney-in-fact)

February 27, 2012

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ENTERGY TEXAS, INC.

SIGNATURES

ENTERGY TEXAS, INC.

By /s/ Theodore H. Bunting, Jr.

Theodore H. Bunting, Jr.

Senior Vice President and Chief Accounting Officer

Date: February 27, 2012

Signature	Title	Date


/s/ Theodore H. Bunting, Jr. Theodore H. Bunting, Jr.	Senior Vice President and Chief Accounting Officer (Principal Accounting Officer and acting Principal Financial Officer)	February 27, 2012

Joseph F. Domino (Chairman of the Board, President, Chief Executive Officer, and Director; Principal Executive Officer); Leo P. Denault, Mark T. Savoff, and Gary J. Taylor (Directors).

By: /s/ Theodore H. Bunting, Jr.

(Theodore H. Bunting, Jr., Attorney-in-fact)

February 27, 2012

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SYSTEM ENERGY RESOURCES, INC.

SIGNATURES

SYSTEM ENERGY RESOURCES, INC.

By /s/ Theodore H. Bunting, Jr.

Theodore H. Bunting, Jr.

Senior Vice President and Chief Accounting Officer

Date: February 27, 2012

Signature	Title	Date


/s/ Theodore H. Bunting, Jr. Theodore H. Bunting, Jr.	Senior Vice President and Chief Accounting Officer (Principal Accounting Officer)	February 27, 2012

John T. Herron (Chairman, President, Chief Executive Officer, and Director; Principal Executive Officer); Wanda C. Curry (Vice President, Chief Financial Officer - Nuclear Operations; Principal Financial Officer); Leo P. Denault and Steven C. McNeal (Directors).

By: /s/ Theodore H. Bunting, Jr.

(Theodore H. Bunting, Jr., Attorney-in-fact)

February 27, 2012

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CONSENTS OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We consent to the incorporation by reference in Post-Effective Amendments Nos. 1 and 2 on Form S-3 and their related prospectus to Registration Statement No. 333-169315, Post -Effective Amendments Nos. 3 and 5A on Form S-8 and their related prospectuses to Registration Statement No. 33-54298 on Form S-4, and in Registration Statements Nos. 333-55692, 333-68950, 333-75097, 333-90914, 333-98179, 333-140183, 333-142055, 333-168664, and 333-174148 on Form S-8 of our reports dated February 27, 2012, relating to the consolidated financial statements and financial statement schedule of Entergy Corporation and Subsidiaries, and the effectiveness of Entergy Corporation and Subsidiaries’ internal control over financial reporting, appearing in this Annual Report on Form 10-K of Entergy Corporation and Subsidiaries for the year ended December 31, 2011.

We consent to the incorporation by reference in Post-Effective Amendment Nos. 1 and 2 on Form S-3, and their related prospectus to Registration Statement No. 333-169315-03 on Form S-3 of our reports dated February 27, 2012, relating to the consolidated financial statements and financial statement schedule of Entergy Arkansas, Inc. and Subsidiaries, and the effectiveness of Entergy Arkansas, Inc. and Subsidiaries’ internal control over financial reporting, appearing in this Annual Report on Form 10-K of Entergy Arkansas, Inc. and Subsidiaries for the year ended December 31, 2011.

We consent to the incorporation by reference in Post-Effective Amendment Nos. 1 and 2 on Form S-3 and their related prospectus to Registration Statement No. 333-169315-02 on Form S-3 of our reports dated February 27, 2012 relating to the financial statements and financial statement schedule of Entergy Gulf States Louisiana, L.L.C., and the effectiveness of Entergy Gulf States Louisiana, L.L.C.’s internal control over financial reporting, appearing in this Annual Report on Form 10-K of Entergy Gulf States Louisiana, L.L.C. for the year ended December 31, 2011.

We consent to the incorporation by reference in Post-Effective Amendment Nos. 1 and 2 on Form S-3 and their related prospectus to Registration Statement No. 333-169315-01 on Form S-3 of our reports dated February 27, 2012, relating to the consolidated financial statements and financial statement schedule of Entergy Louisiana, LLC and Subsidiaries, and the effectiveness of Entergy Louisiana, LLC and Subsidiaries’ internal control over financial reporting, appearing in this Annual Report on Form 10-K of Entergy Louisiana, LLC and Subsidiaries for the year ended December 31, 2011.

We consent to the incorporation by reference in Post-Effective Amendment No. 2 on Form S-3 and its related prospectus to Registration Statement No. 333-169315-07 on Form S-3 of our reports dated February 27, 2012, relating to the financial statements and financial statement schedule of Entergy Mississippi, Inc., and the effectiveness of Entergy Mississippi, Inc.’s internal control over financial reporting, appearing in this Annual Report on Form 10-K of Entergy Mississippi, Inc. for the year ended December 31, 2011.

We consent to the incorporation by reference in Post-Effective Amendment No. 2 on Form S-3 and its related prospectus to Registration Statement No. 333-169315-06 on Form S-3 of our reports dated February 27, 2012, relating to the financial statements and financial statement schedule of Entergy New Orleans, Inc., and the effectiveness of Entergy New Orleans, Inc.’s internal control over financial reporting, appearing in this Annual Report on Form 10-K of Entergy New Orleans, Inc. for the year ended December 31, 2011.

We consent to the incorporation by reference in Post-Effective Amendment No. 2 on Form S-3 and its related prospectus to Registration Statement No. 333-169315-05 on Form S-3 of our reports dated February 27, 2012, relating to the consolidated financial statements and financial statement schedule of Entergy Texas, Inc. and Subsidiaries, and the effectiveness of Entergy Texas, Inc. and Subsidiaries’ internal control over financial reporting, appearing in this Annual Report on Form 10-K of Entergy Texas, Inc. and Subsidiaries for the year ended December 31, 2011.

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We consent to the incorporation by reference in Post-Effective Amendment No. 2 on Form S-3 and its related prospectus to Registration Statement No. 333-169315-04 on Form S-3 of our reports dated February 27, 2012, relating to the financial statements of System Energy Resources, Inc., and the effectiveness of System Energy Resources, Inc.’s internal control over financial reporting, appearing in this Annual Report on Form 10-K of System Energy Resources, Inc. for the year ended December 31, 2011.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of

Entergy Corporation and Subsidiaries

Entergy Arkansas, Inc. and Subsidiaries

Entergy Mississippi, Inc.

Entergy New Orleans, Inc.

Entergy Texas, Inc. and Subsidiaries

To the Board of Directors and Members of

Entergy Gulf States Louisiana, L.L.C.

Entergy Louisiana, LLC and Subsidiaries

We have audited the consolidated financial statements of Entergy Corporation and Subsidiaries, Entergy Arkansas, Inc. and Subsidiaries, Entergy Louisiana, LLC and Subsidiaries, and Entergy Texas, Inc. and Subsidiaries, and we have also audited the financial statements of Entergy Gulf States Louisiana, L.L.C., Entergy Mississippi, Inc., and Entergy New Orleans, Inc. (collectively the “Companies”) as of December 31, 2011 and 2010, and for each of the three years in the period ended December 31, 2011, and the respective Companies’ internal control over financial reporting as of December 31, 2011, and have issued our reports thereon dated February 27, 2012; such reports are included elsewhere in this Form 10-K. Our audits also included the financial statement schedules of the respective Companies listed in Item 15. These financial statement schedules are the responsibility of the respective Companies’ management. Our responsibility is to express an opinion based on our audits. In our opinion, such financial statement schedules, when considered in relation to the basic financial statements taken as a whole, present fairly, in all material respects, the information set forth therein.

/s/ DELOITTE & TOUCHE LLP

New Orleans, Louisiana

February 27, 2012

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INDEX TO FINANCIAL STATEMENT SCHEDULES

Schedule		Page

II	Valuation and Qualifying Accounts 2011, 2010 and 2009:
	Entergy Corporation and Subsidiaries	S-2
	Entergy Arkansas, Inc. and Subsidiaries	S-3
	Entergy Gulf States Louisiana, L.L.C.	S-4
	Entergy Louisiana, LLC and Subsidiaries	S-5
	Entergy Mississippi, Inc.	S-6
	Entergy New Orleans, Inc.	S-7
	Entergy Texas, Inc. and Subsidiaries	S-8

Schedules other than those listed above are omitted because they are not required, not applicable, or the required information is shown in the financial statements or notes thereto.

Columns have been omitted from schedules filed because the information is not applicable.

S-1

Table of Contents

ENTERGY CORPORATION AND SUBSIDIARIES

SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
Years Ended December 31, 2011, 2010, and 2009
(In Thousands)

Column A	Column B		Column C		Column D			Column E
					Other
			Additions		Changes
					Deductions
	Balance at				from			Balance
	Beginning		Charged to Income		Provisions			at End
Description	of Period		or Regulatory Assets			(1)		of Period
Year ended December 31, 2011
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	31,777	$	512	$	1,130		$	31,159
Accumulated Provisions Not
Deducted from Assets (2)	$	395,250	$	46,792	$	56,530		$	385,512

Year ended December 31, 2010
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	27,631	$	1,569	$	(2,577	)	$	31,777
Accumulated Provisions Not
Deducted from Assets (2)	$	141,315	$	333,371	$	79,436		$	395,250

Year ended December 31, 2009
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	25,610	$	2,021	$	-		$	27,631
Accumulated Provisions Not
Deducted from Assets (3)	$	147,452	$	52,050	$	58,187		$	141,315
___________
Notes:
(1) Deductions from provisions represent losses or expenses for which the respective provisions were
created. In the case of the provision for doubtful accounts, such deductions are reduced by recoveries
of amounts previously written off.

(2) Accumulated provisions not deducted from assets includes provisions for storm damage, property insurance, injuries and damages,
and environmental items.

(3) Accumulated provisions not deducted from assets includes provisions for storm damage, property insurance, injuries and damages, environmental,
and pension related items.

S-2

Table of Contents

ENTERGY ARKANSAS, INC. AND SUBSIDIARIES

SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
Years Ended December 31, 2011, 2010, and 2009
(In Thousands)

Column A	Column B		Column C		Column D		Column E
					Other
			Additions		Changes
					Deductions
	Balance at				from		Balance
	Beginning		Charged to Income		Provisions		at End
Description	of Period		or Regulatory Assets			(1)	of Period
Year ended December 31, 2011
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	24,402	$	1,753	$	-	$	26,155
Accumulated Provisions Not
Deducted from Assets (2)	$	7,970	$	19,424	$	21,754	$	5,640

Year ended December 31, 2010
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	21,853	$	2,549	$	-	$	24,402
Accumulated Provisions Not
Deducted from Assets (2)	$	13,217	$	21,088	$	26,335	$	7,970

Year ended December 31, 2009
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	19,882	$	1,971	$	-	$	21,853
Accumulated Provisions Not
Deducted from Assets (3)	$	15,925	$	17,076	$	19,784	$	13,217
___________
Notes:
(1) Deductions from provisions represent losses or expenses for which the respective provisions were
created. In the case of the provision for doubtful accounts, such deductions are reduced by recoveries
of amounts previously written off.

(2) Accumulated provisions not deducted from assets includes provisions for storm damage, property insurance, injuries and damages,
and environmental items.

(3) Accumulated provisions not deducted from assets includes provisions for storm damage, property insurance, injuries and damages, environmental,
and pension related items.

S-3

Table of Contents

ENTERGY GULF STATES LOUISIANA, L.L.C.

SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
Years Ended December 31, 2011, 2010, and 2009
(In Thousands)

Column A	Column B		Column C			Column D			Column E
						Other
			Additions			Changes
						Deductions
	Balance at					from			Balance
	Beginning		Charged to Income			Provisions			at End
Description	of Period		or Regulatory Assets				(1)		of Period
Year ended December 31, 2011
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	1,306	$	(235	)	$	228		$	843
Accumulated Provisions
Not Deducted from Assets (2)	$	97,680	$	10,098		$	8,745		$	99,033

Year ended December 31, 2010
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	1,235	$	(413	)	$	(484	)	$	1,306
Accumulated Provisions
Not Deducted from Assets (2)	$	14,669	$	92,647		$	9,636		$	97,680

Year ended December 31, 2009
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	1,230	$	5		$	-		$	1,235
Accumulated Provisions
Not Deducted from Assets (3)	$	13,896	$	7,660		$	6,887		$	14,669
___________
Notes:
(1) Deductions from provisions represent losses or expenses for which the respective provisions were
created. In the case of the provision for doubtful accounts, such deductions are reduced by recoveries
of amounts previously written off.

(2) Accumulated provisions not deducted from assets includes provisions for storm damage, property insurance, injuries and damages,
and environmental items.

(3) Accumulated provisions not deducted from assets includes provisions for storm damage, property insurance, injuries and damages, environmental,
and pension related items.

S-4

Table of Contents

ENTERGY LOUISIANA, LLC AND SUBSIDIARIES

SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
Years Ended December 31, 2011, 2010, and 2009
(In Thousands)

Column A	Column B		Column C			Column D			Column E
						Other
			Additions			Changes
						Deductions
	Balance at					from			Balance
	Beginning		Charged to Income			Provisions			at End
Description	of Period		or Regulatory Assets				(1)		of Period

Year ended December 31, 2011
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	1,961	$	(453	)	$	361		$	1,147
Accumulated Provisions Not
Deducted from Assets (2)	$	223,556	$	6,014		$	16,510		$	213,060

Year ended December 31, 2010
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	1,312	$	(112	)	$	(761	)	$	1,961
Accumulated Provisions Not
Deducted from Assets (2)	$	20,301	$	206,832		$	3,577		$	223,556


Year ended December 31, 2009
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	1,698	$	(386	)	$	-		$	1,312
Accumulated Provisions Not
Deducted from Assets (3)	$	19,916	$	7,851		$	7,466		$	20,301

___________
Notes:
(1) Deductions from provisions represent losses or expenses for which the respective provisions were
created. In the case of the provision for doubtful accounts, such deductions are reduced by recoveries
of amounts previously written off.

(2) Accumulated provisions not deducted from assets includes provisions for storm damage, property insurance, injuries and damages,
and environmental items.

(3) Accumulated provisions not deducted from assets includes provisions for storm damage, property insurance, injuries and damages, environmental,
and pension related items.

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ENTERGY MISSISSIPPI, INC.

SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
Years Ended December 31, 2011, 2010, and 2009
(In Thousands)

Column A	Column B		Column C			Column D		Column E
						Other
			Additions			Changes
						Deductions
	Balance at					from		Balance
	Beginning		Charged to Income			Provisions		at End
Description	of Period		or Regulatory Assets				(1)	of Period
Year ended December 31, 2011
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	985	$	(229	)	$	-	$	756
Accumulated Provisions Not
Deducted from Assets (2)	$	39,466	$	645		$	1,822	$	38,289

Year ended December 31, 2010
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	1,018	$	(33	)	$	-	$	985
Accumulated Provisions Not
Deducted from Assets (2)	$	41,403	$	3,176		$	5,113	$	39,466

Year ended December 31, 2009
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	687	$	331		$	-	$	1,018
Accumulated Provisions Not
Deducted from Assets (3)	$	36,957	$	11,411		$	6,965	$	41,403

___________
Notes:
(1) Deductions from provisions represent losses or expenses for which the respective provisions were
created. In the case of the provision for doubtful accounts, such deductions are reduced by recoveries
of amounts previously written off.

(2) Accumulated provisions not deducted from assets includes provisions for storm damage, property insurance, injuries and damages,
and environmental items.

(3) Accumulated provisions not deducted from assets includes provisions for storm damage, property insurance, injuries and damages, environmental,
and pension related items.

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ENTERGY NEW ORLEANS, INC.

SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
Years Ended December 31, 2011, 2010, and 2009
(In Thousands)

Column A	Column B		Column C			Column D			Column E
						Other
			Additions			Changes
						Deductions
	Balance at					from			Balance
	Beginning		Charged to Income			Provisions			at End
Description	of Period		or Regulatory Assets				(1)		of Period
Year ended December 31, 2011
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	734	$	(241	)	$	28		$	465
Accumulated Provisions Not
Deducted from Assets (2)	$	11,206	$	9,203		$	4,566		$	15,843

Year ended December 31, 2010
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	1,166	$	(491	)	$	(59	)	$	734
Accumulated Provisions Not
Deducted from Assets (2)	$	15,991	$	7,766		$	12,551		$	11,206

Year ended December 31, 2009
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	1,112	$	54		$	-		$	1,166
Accumulated Provisions Not
Deducted from Assets (3)	$	10,609	$	2,187		$	(3,195	)	$	15,991

___________
Notes:
(1) Deductions from provisions represent losses or expenses for which the respective provisions were
created. In the case of the provision for doubtful accounts, such deductions are reduced by recoveries
of amounts previously written off.

(2) Accumulated provisions not deducted from assets includes provisions for storm damage, property insurance, injuries and damages,
and environmental items.

(3) Accumulated provisions not deducted from assets includes provisions for storm damage, property insurance, injuries and damages, environmental,
and pension related items.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES

SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
Years Ended December 31, 2011, 2010, and 2009
(In Thousands)

Column A	Column B		Column C			Column D			Column E
						Other
			Additions			Changes
						Deductions
	Balance at					from			Balance
	Beginning		Charged to Income			Provisions			at End
Description	of Period		or Regulatory Assets				(1)		of Period
Year ended December 31, 2011
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	2,185	$	(212	)	$	512		$	1,461
Accumulated Provisions Not
Deducted from Assets (2)	$	5,320	$	2,321		$	2,617		$	5,024

Year ended December 31, 2010
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	844	$	69		$	(1,272	)	$	2,185
Accumulated Provisions Not
Deducted from Assets (2)	$	8,710	$	1,629		$	5,019		$	5,320

Year ended December 31, 2009
Accumulated Provisions
Deducted from Assets--
Doubtful Accounts	$	1,001	$	(157	)	$	-		$	844
Accumulated Provisions Not
Deducted from Assets (3)	$	12,936	$	4,944		$	9,170		$	8,710

___________
Notes:
(1) Deductions from provisions represent losses or expenses for which the respective provisions were
created. In the case of the provision for doubtful accounts, such deductions are reduced by recoveries
of amounts previously written off.

(2) Accumulated provisions not deducted from assets includes provisions for storm damage, property insurance, injuries and damages
and environmental items.

(3) Accumulated provisions not deducted from assets includes provisions for storm damage, property insurance, injuries and damages, environmental,
and pension related items.

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EXHIBIT INDEX

The following exhibits indicated by an asterisk preceding the exhibit number are filed herewith. The balance of the exhibits have heretofore been filed with the SEC as the exhibits and in the file numbers indicated and are incorporated herein by reference. The exhibits marked with a (+) are management contracts or compensatory plans or arrangements required to be filed herewith and required to be identified as such by Item 15 of Form 10-K.

Some of the agreements included or incorporated by reference as exhibits to this Form 10-K contain representations and warranties by each of the parties to the applicable agreement. These representations and warranties were made solely for the benefit of the other parties to the applicable agreement and (i) were not intended to be treated as categorical statements of fact, but rather as a way of allocating the risk to one of the parties if those statements prove to be inaccurate; (ii) may have been qualified in such agreement by disclosures that were made to the other party in connection with the negotiation of the applicable agreement; (iii) may apply contract standards of “materiality” that are different from the standard of “materiality” under the applicable securities laws; and (iv) were made only as of the date of the applicable agreement or such other date or dates as may be specified in the agreement.

Entergy acknowledges that, notwithstanding the inclusion of the foregoing cautionary statements, it is responsible for considering whether additional specific disclosures of material information regarding material contractual provisions are required to make the statements in this Form 10-K not misleading.

(2) Plan of Acquisition, Reorganization, Arrangement, Liquidation or Succession

Entergy Corporation

(a) 1 --	Merger Agreement, dated as of December 4, 2011, among Entergy Corporation, Mid South TransCo LLC, ITC Holdings Corp. and Ibis Transaction Subsidiary LLC (2.1 to Form 8-K filed December 6, 2011 in 1-11299).

(a) 2 --	Separation Agreement, dated as of December 4, 2011, among Entergy Corporation, ITC Holdings Corp., Mid South TransCo LLC, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas and Entergy Services, Inc. (2.2 to Form 8-K filed December 6, 2011 in 1-11299).

Entergy Gulf States Louisiana

(b) 1 --	Plan of Merger of Entergy Gulf States, Inc. effective December 31, 2007 (2(ii) to Form 8-K15D5 filed January 7, 2008 in 333-148557).

(b) 2 --	Separation Agreement, dated as of December 4, 2011, among Entergy Corporation, ITC Holdings Corp., Mid South TransCo LLC, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas and Entergy Services, Inc. (2.2 to Form 8-K filed December 6, 2011 in 1-11299).

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas

Separation Agreement, dated as of December 4, 2011, among Entergy Corporation, ITC Holdings Corp., Mid South TransCo LLC, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas and Entergy Services, Inc. (2.2 to Form 8-K filed December 6, 2011 in 1-11299).

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(3) Articles of Incorporation and By-laws

Entergy Corporation

(a) 1 --	Restated Certificate of Incorporation of Entergy Corporation dated October 10, 2006 (3(a) to Form 10-Q for the quarter ended September 30, 2006).

(a) 2 --	By-Laws of Entergy Corporation as amended February 12, 2007, and as presently in effect (3(ii) to Form 8-K filed February 16, 2007 in 1-11299).

System Energy

(b) 1 --	Amended and Restated Articles of Incorporation of System Energy and amendments thereto through April 28, 1989 (A-1(a) to Form U-1 in 70-5399).

(b) 2 --	By-Laws of System Energy effective July 6, 1998, and as presently in effect (3(f) to Form 10-Q for the quarter ended June 30, 1998 in 1-9067).

Entergy Arkansas

(c) 1 --	Articles of Amendment and Restatement for the Second Amended and Restated Articles of Incorporation of Entergy Arkansas, effective August 19, 2009 (3 to Form 8-K filed August 24, 2009 in 1-10764).

(c) 2 --	By-Laws of Entergy Arkansas effective November 26, 1999, and as presently in effect (3(ii)(c) to Form 10-K for the year ended December 31, 1999 in 1-10764).

Entergy Gulf States Louisiana

(d) 1 --	Articles of Organization of Entergy Gulf States Louisiana effective December 31, 2007 (3(i) to Form 8-K15D5 filed January 7, 2008 in 333-148557).

(d) 2 --	Operating Agreement of Entergy Gulf States Louisiana, effective as of December 31, 2007 (3(ii) to Form 8-K15D5 filed January 7, 2008 in 333-148557).

Entergy Louisiana

(e) 1 --	Articles of Organization of Entergy Louisiana effective December 31, 2005 (3(c) to Form 8-K filed January 6, 2006 in 1-32718).

(e) 2 --	Regulations of Entergy Louisiana effective December 31, 2005, and as presently in effect (3(d) to Form 8-K filed January 6, 2006 in 1-32718).

Entergy Mississippi

(f) 1 --	Second Amended and Restated Articles of Incorporation of Entergy Mississippi, effective July 21, 2009 (99.1 to Form 8-K filed July 27, 2009 in 1-31508).

(f) 2 --	By-Laws of Entergy Mississippi effective November 26, 1999, and as presently in effect (3(ii)(f) to Form 10-K for the year ended December 31, 1999 in 0-320).

Entergy New Orleans

(g) 1 --	Amended and Restated Articles of Incorporation of Entergy New Orleans, effective May 8, 2007 (3(a) to Form 10-Q for the quarter ended March 31, 2007 in 0-5807).

(g) 2 --	Amended By-Laws of Entergy New Orleans effective May 8, 2007, and as presently in effect (3(b) to Form 10-Q for the quarter ended March 31, 2007 in 0-5807).

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Entergy Texas

(h) 1 --	Certificate of Formation of Entergy Texas, effective December 31, 2007 (3(i) to Form 10 filed March 14, 2008 in 000-53134).

(h) 2 --	Bylaws of Entergy Texas effective December 31, 2007 (3(ii) to Form 10 filed March 14, 2008 in 000-53134).

(4)	Instruments Defining Rights of Security Holders, Including Indentures

Entergy Corporation

(a) 1 --	See (4)(b) through (4)(h) below for instruments defining the rights of holders of long-term debt of System Energy, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas.

(a) 2 --	Credit Agreement ($3,500,000,000), dated as of August 2, 2007, among Entergy Corporation, the Banks (Citibank, N.A., ABN AMRO Bank N.V., Barclays Bank PLC, BNP Paribas, Calyon New York Branch, Credit Suisse (Cayman Islands Branch), J. P. Morgan Chase Bank, N.A., KeyBank National Association, Lehman Brothers Bank (FSB), Mizuho Corporate Bank, Ltd., Morgan Stanley Bank, Regions Bank, Societe Generale, The Bank of New York, The Bank of Nova Scotia, The Bank of Toyko-Mitsubishi UFJ, Ltd. (New York Branch), The Royal Bank of Scotland plc, Union Bank of California, N.A., Wachovia Bank, National Association and William Street Commitment Corporation), Citibank, N.A., as Administrative Agent and LC Issuing Bank, and ABN AMRO Bank, N.V., as LC Issuing Bank (10(a) to Form 10-Q for the quarter ended June 30, 2007 in 1-11299).

(a) 3 --	Indenture (For Unsecured Debt Securities), dated as of September 1, 2010, between Entergy Corporation and Wells Fargo Bank, National Association (4.01 to Form 8-K filed September 16, 2010 in 1-11299).

(a) 4 --	Officer’s Certificate for Entergy Corporation relating to 3.625% Senior Notes due September 15, 2015 (4.02(a) to Form 8-K filed September 16, 2010 in 1-11299).

(a) 5 --	Officer’s Certificate for Entergy Corporation relating to 5.125% Senior Notes due September 15, 2020 (4.02(b) to Form 8-K filed September 16, 2010 in 1-11299).

(a) 6 --	Officer’s Certificate for Entergy Corporation relating to 4.70% Senior Notes due January 15, 2017 (4.02 to Form 8-K filed January 13, 2012 in 1-11299).

System Energy

(b) 1 --

Mortgage and Deed of Trust, dated as of June 15, 1977, as amended by twenty-three Supplemental Indentures (A-1 in 70-5890 (Mortgage); B and C to Rule 24 Certificate in 70-5890 (First); B to Rule 24 Certificate in 70-6259 (Second); 20(a)-5 to Form 10-Q for the quarter ended June 30, 1981 in 1-3517 (Third); A-1(e)-1 to Rule 24 Certificate in 70-6985 (Fourth); B to Rule 24 Certificate in 70-7021 (Fifth); B to Rule 24 Certificate in 70-7021 (Sixth); A-3(b) to Rule 24 Certificate in 70-7026 (Seventh); A-3(b) to Rule 24 Certificate in 70-7158 (Eighth); B to Rule 24 Certificate in 70-7123 (Ninth); B-1 to Rule 24 Certificate in 70-7272 (Tenth); B-2 to Rule 24 Certificate in 70-7272 (Eleventh); B-3 to Rule 24 Certificate in 70-7272 (Twelfth); B-1 to Rule 24 Certificate in 70-7382 (Thirteenth); B-2 to Rule 24 Certificate in 70-7382 (Fourteenth); A-2(c) to Rule 24 Certificate in 70-7946 (Fifteenth); A-2(c) to Rule 24 Certificate in 70-7946 (Sixteenth); A-2(d) to Rule 24 Certificate in 70-7946 (Seventeenth); A-2(e) to Rule 24 Certificate dated May 4, 1993 in 70-7946 (Eighteenth); A-2(g) to Rule 24 Certificate dated May 6, 1994 in 70-7946 (Nineteenth); A-2(a)(1) to Rule 24 Certificate dated August 8, 1996 in 70-8511 (Twentieth); A-2(a)(2) to Rule 24 Certificate dated August 8, 1996 in 70-8511 (Twenty-first); A-2(a) to Rule 24 Certificate filed October 4, 2002 in 70-9753 (Twenty-second); and 4(b) to Form 10-Q for the quarter ended September 30, 2007 in 1-9067 (Twenty-third)).

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(b) 2 --	Facility Lease No. 1, dated as of December 1, 1988, between Meridian Trust Company and Stephen M. Carta (Steven Kaba, successor), as Owner Trustees, and System Energy (B-2(c)(1) to Rule 24 Certificate dated January 9, 1989 in 70-7561), as supplemented by Lease Supplement No. 1 dated as of April 1, 1989 (B-22(b) (1) to Rule 24 Certificate dated April 21, 1989 in 70-7561), Lease Supplement No. 2 dated as of January 1, 1994 (B-3(d) to Rule 24 Certificate dated January 31, 1994 in 70-8215), and Lease Supplement No. 3 dated as of May 1, 2004 (B-3(d) to Rule 24 Certificate dated June 4, 2004 in 70-10182).

(b) 3 --	Facility Lease No. 2, dated as of December 1, 1988 between Meridian Trust Company and Stephen M. Carta (Steven Kaba, successor), as Owner Trustees, and System Energy (B-2(c)(2) to Rule 24 Certificate dated January 9, 1989 in 70-7561), as supplemented by Lease Supplement No. 1 dated as of April 1, 1989 (B-22(b) (2) to Rule 24 Certificate dated April 21, 1989 in 70-7561), Lease Supplement No. 2 dated as of January 1, 1994 (B-4(d) Rule 24 Certificate dated January 31, 1994 in 70-8215), and Lease Supplement No. 3 dated as of May 1, 2004 (B-4(d) to Rule 24 Certificate dated June 4, 2004 in 70-10182).

Entergy Arkansas

Mortgage and Deed of Trust, dated as of October 1, 1944, as amended by seventy Supplemental Indentures (7(d) in 2-5463 (Mortgage); 7(b) in 2-7121 (First); 7(c) in 2-7605 (Second); 7(d) in 2-8100 (Third); 7(a)-4 in 2-8482 (Fourth); 7(a)-5 in 2-9149 (Fifth); 4(a)-6 in 2-9789 (Sixth); 4(a)-7 in 2-10261 (Seventh); 4(a)-8 in 2-11043 (Eighth); 2(b)-9 in 2-11468 (Ninth); 2(b)-10 in 2-15767 (Tenth); D in 70-3952 (Eleventh); D in 70-4099 (Twelfth); 4(d) in 2-23185 (Thirteenth); 2(c) in 2-24414 (Fourteenth); 2(c) in 2-25913 (Fifteenth); 2(c) in 2-28869 (Sixteenth); 2(d) in 2-28869 (Seventeenth); 2(c) in 2-35107 (Eighteenth); 2(d) in 2-36646 (Nineteenth); 2(c) in 2-39253 (Twentieth); 2(c) in 2-41080 (Twenty-first); C-1 to Rule 24 Certificate in 70-5151 (Twenty-second); C-1 to Rule 24 Certificate in 70-5257 (Twenty-third); C to Rule 24 Certificate in 70-5343 (Twenty-fourth); C-1 to Rule 24 Certificate in 70-5404 (Twenty-fifth); C to Rule 24 Certificate in 70-5502 (Twenty-sixth); C-1 to Rule 24 Certificate in 70-5556 (Twenty-seventh); C-1 to Rule 24 Certificate in 70-5693 (Twenty-eighth); C-1 to Rule 24 Certificate in 70-6078 (Twenty-ninth); C-1 to Rule 24 Certificate in 70-6174 (Thirtieth); C-1 to Rule 24 Certificate in 70-6246 (Thirty-first); C-1 to Rule 24 Certificate in 70-6498 (Thirty-second); A-4b-2 to Rule 24 Certificate in 70-6326 (Thirty-third); C-1 to Rule 24 Certificate in 70-6607 (Thirty-fourth); C-1 to Rule 24 Certificate in 70-6650 (Thirty-fifth); C-1 to Rule 24 Certificate dated December 1, 1982 in 70-6774 (Thirty-sixth); C-1 to Rule 24 Certificate dated February 17, 1983 in 70-6774 (Thirty-seventh); A-2(a) to Rule 24 Certificate dated December 5, 1984 in 70-6858 (Thirty-eighth); A-3(a) to Rule 24 Certificate in 70-7127 (Thirty-ninth); A-7 to Rule 24 Certificate in 70-7068 (Fortieth); A-8(b) to Rule 24 Certificate dated July 6, 1989 in 70-7346 (Forty-first); A-8(c) to Rule 24 Certificate dated February 1, 1990 in 70-7346 (Forty-second); 4 to Form 10-Q for the quarter ended September 30, 1990 in 1-10764 (Forty-third); A-2(a) to Rule 24 Certificate dated November 30, 1990 in 70-7802 (Forty-fourth); A-2(b) to Rule 24 Certificate dated January 24, 1991 in 70-7802 (Forty-fifth); 4(d)(2) in 33-54298 (Forty-sixth); 4(c)(2) to Form 10-K for the year ended December 31, 1992 in 1-10764 (Forty-seventh); 4(b) to Form 10-Q for the quarter ended June 30, 1993 in 1-10764 (Forty-eighth); 4(c) to Form 10-Q for the quarter ended June 30, 1993 in 1-10764 (Forty-ninth); 4(b) to Form 10-Q for the quarter ended September 30, 1993 in 1-10764 (Fiftieth); 4(c) to Form 10-Q for the quarter ended September 30, 1993 in 1-10764 (Fifty-first); 4(a) to Form 10-Q for the quarter ended June 30, 1994 in 1-10764 (Fifty-second); C-2 to Form U5S for the year ended December 31, 1995 (Fifty-third); C-2(a) to Form U5S for the year ended December 31, 1996 (Fifty-fourth); 4(a) to Form 10-Q for the quarter ended March 31, 2000 in 1-10764 (Fifty-fifth); 4(a) to Form 10-Q for the quarter ended September 30, 2001 in 1-10764 (Fifty-sixth); C-2(a) to Form U5S for the year ended December 31, 2001 (Fifty-seventh); 4(c)1 to Form 10-K for the year December 31, 2002 in 1-10764 (Fifty-eighth); 4(a) to Form 10-Q for the quarter ended June 30, 2003 in 1-10764 (Fifty-ninth); 4(f) to Form 10-Q for the quarter ended June 30, 2003 in 1-10764 (Sixtieth); 4(h) to Form 10-Q for the quarter ended June 30, 2003 in 1-10764 (Sixty-first); 4(e) to Form 10-Q for the quarter ended September 30, 2004 in 1-10764 (Sixty-second); 4(c)1 to Form 10-K for the year December 31, 2004 in 1-10764 (Sixty-third); C-2(a) to Form U5S for the year ended December 31, 2004 (Sixty-fourth); 4(c) to Form 10-Q for the quarter ended June 30, 2005 in 1-10764 (Sixty-fifth); 4(a) to Form 10-Q for the quarter ended June 30, 2006 in 1-10764 (Sixty-sixth); 4(b) to Form 10-Q for the quarter ended June 30, 2008 in 1-10764 (Sixty-seventh); 4(c)1 to Form 10-K for the year ended December 31, 2008 in 1-10764 (Sixty-eighth); 4.06 to Form 8-K dated October 8, 2010 in 1-10764 (Sixty-ninth); and 4.06 to Form 8-K dated November 12, 2010 in 1-10764 (Seventieth)).

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Entergy Gulf States Louisiana

(d) 1 --	Indenture of Mortgage, dated September 1, 1926, as amended by certain Supplemental Indentures (B-a-I-1 in Registration No. 2-2449 (Mortgage); 7-A-9 in Registration No. 2-6893 (Seventh); B to Form 8-K dated September 1, 1959 (Eighteenth); B to Form 8-K dated February 1, 1966 (Twenty-second); B to Form 8-K dated March 1, 1967 (Twenty-third); C to Form 8-K dated March 1, 1968 (Twenty-fourth); B to Form 8-K dated November 1, 1968 (Twenty-fifth); B to Form 8-K dated April 1, 1969 (Twenty-sixth); 2-A-8 in Registration No. 2-66612 (Thirty-eighth); 4-2 to Form 10-K for the year ended December 31, 1984 in 1-27031 (Forty-eighth); 4-2 to Form 10-K for the year ended December 31, 1988 in 1-27031 (Fifty-second); 4 to Form 10-K for the year ended December 31, 1991 in 1-27031 (Fifty-third); 4 to Form 8-K dated July 29, 1992 in 1-27031 (Fifth-fourth); 4 to Form 10-K dated December 31, 1992 in 1-27031 (Fifty-fifth); 4 to Form 10-Q for the quarter ended March 31, 1993 in 1-27031 (Fifty-sixth); 4-2 to Amendment No. 9 to Registration No. 2-76551 (Fifty-seventh); 4(b) to Form 10-Q for the quarter ended March 31,1999 in 1-27031 (Fifty-eighth); A-2(a) to Rule 24 Certificate dated June 23, 2000 in 70-8721 (Fifty-ninth); A-2(a) to Rule 24 Certificate dated September 10, 2001 in 70-9751 (Sixtieth); A-2(b) to Rule 24 Certificate dated November 18, 2002 in 70-9751 (Sixty-first); A-2(c) to Rule 24 Certificate dated December 6, 2002 in 70-9751 (Sixty-second); A-2(d) to Rule 24 Certificate dated June 16, 2003 in 70-9751 (Sixty-third); A-2(e) to Rule 24 Certificate dated June 27, 2003 in 70-9751 (Sixty-fourth); A-2(f) to Rule 24 Certificate dated July 11, 2003 in 70-9751 (Sixty-fifth); A-2(g) to Rule 24 Certificate dated July 28, 2003 in 70-9751 (Sixty-sixth); A-3(i) to Rule 24 Certificate dated November 4, 2004 in 70-10158 (Sixty-seventh); A-3(ii) to Rule 24 Certificate dated November 23, 2004 in 70-10158 (Sixty-eighth); A-3(iii) to Rule 24 Certificate dated February 16, 2005 in 70-10158 (Sixty-ninth); A-3(iv) to Rule 24 Certificate dated June 2, 2005 in 70-10158 (Seventieth); A-3(v) to Rule 24 Certificate dated July 21, 2005 in 70-10158 (Seventy-first); A-3(vi) to Rule 24 Certificate dated October 7, 2005 in 70-10158 (Seventy-second); A-3(vii) to Rule 24 Certificate dated December 19, 2005 in 70-10158 (Seventy-third); 4(a) to Form 10-Q for the quarter ended March 31, 2006 in 1-27031 (Seventy-fourth); 4(iv) to Form 8-K15D5 dated January 7, 2008 in 333-148557 (Seventy-fifth); 4(a) to Form 10-Q for the quarter ended June 30, 2008 in 333-148557 (Seventy-sixth); 4(a) to Form 10-Q for the quarter ended September 30, 2009 in 0-20371 (Seventy-seventh); 4.07 to Form 8-K dated October 1, 2010 in 0-20371 (Seventy-eighth); 4(c) to Form 8-K filed October 12, 2010 in 0-20371 (Seventy-ninth); and 4(f) to Form 8-K filed October 12, 2010 in 0-20371 (Eightieth)).

(d) 2 --	Indenture, dated March 21, 1939, accepting resignation of The Chase National Bank of the City of New York as trustee and appointing Central Hanover Bank and Trust Company as successor trustee (B-a-1-6 in Registration No. 2-4076).

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(d) 3 --	Agreement of Resignation, Appointment and Acceptance, dated as of October 3, 2007, among Entergy Gulf States, Inc., JPMorgan Chase Bank, National Association, as resigning trustee, and The Bank of New York, as successor trustee (4(a) to Form 10-Q for the quarter ended September 30, 2007 in 1-27031).

(d) 4 --	Credit Agreement ($200,000,000), dated as of August 2, 2007, among Entergy Gulf States, Inc., the Banks (Citibank, N.A., ABN AMRO Bank N.V., Barclays Bank PLC, BNP Paribas, Calyon New York Branch, Credit Suisse (Cayman Islands Branch), JPMorgan Chase Bank, N.A., KeyBank National Association, Mizuho Corporate Bank, Ltd., Morgan Stanley Bank, The Bank of New York, The Royal Bank of Scotland plc, and Wachovia Bank, National Association), Citibank, N.A., as Administrative Agent, and the LC Issuing Banks (10(c) to Form 10-Q for the quarter ended June 30, 2007 in 1-27031).

(d) 5 --	Assumption Agreement, dated as of May 30, 2008, among Entergy Texas, Inc., Entergy Gulf States Louisiana, L.L.C. and Citibank, N.A., as administrative agent (10(a) to Form 10-Q for the quarter ended March 31, 2008 in 0-53134).

Entergy Louisiana

(e) 1 --

Mortgage and Deed of Trust, dated as of April 1, 1944, as amended by seventy-four Supplemental Indentures (7(d) in 2-5317 (Mortgage); 7(b) in 2-7408 (First); 7(c) in 2-8636 (Second); 4(b)-3 in 2-10412 (Third); 4(b)-4 in 2-12264 (Fourth); 2(b)-5 in 2-12936 (Fifth); D in 70-3862 (Sixth); 2(b)-7 in 2-22340 (Seventh); 2(c) in 2-24429 (Eighth); 4(c)-9 in 2-25801 (Ninth); 4(c)-10 in 2-26911 (Tenth); 2(c) in 2-28123 (Eleventh); 2(c) in 2-34659 (Twelfth); C to Rule 24 Certificate in 70-4793 (Thirteenth); 2(b)-2 in 2-38378 (Fourteenth); 2(b)-2 in 2-39437 (Fifteenth); 2(b)-2 in 2-42523 (Sixteenth); C to Rule 24 Certificate in 70-5242 (Seventeenth); C to Rule 24 Certificate in 70-5330 (Eighteenth); C-1 to Rule 24 Certificate in 70-5449 (Nineteenth); C-1 to Rule 24 Certificate in 70-5550 (Twentieth); A-6(a) to Rule 24 Certificate in 70-5598 (Twenty-first); C-1 to Rule 24 Certificate in 70-5711 (Twenty-second); C-1 to Rule 24 Certificate in 70-5919 (Twenty-third); C-1 to Rule 24 Certificate in 70-6102 (Twenty-fourth); C-1 to Rule 24 Certificate in 70-6169 (Twenty-fifth); C-1 to Rule 24 Certificate in 70-6278 (Twenty-sixth); C-1 to Rule 24 Certificate in 70-6355 (Twenty-seventh); C-1 to Rule 24 Certificate in 70-6508 (Twenty-eighth); C-1 to Rule 24 Certificate in 70-6556 (Twenty-ninth); C-1 to Rule 24 Certificate in 70-6635 (Thirtieth); C-1 to Rule 24 Certificate in 70-6834 (Thirty-first); C-1 to Rule 24 Certificate in 70-6886 (Thirty-second); C-1 to Rule 24 Certificate in 70-6993 (Thirty-third); C-2 to Rule 24 Certificate in 70-6993 (Thirty-fourth); C-3 to Rule 24 Certificate in 70-6993 (Thirty-fifth); A-2(a) to Rule 24 Certificate in 70-7166 (Thirty-sixth); A-2(a) in 70-7226 (Thirty-seventh); C-1 to Rule 24 Certificate in 70-7270 (Thirty-eighth); 4(a) to Quarterly Report on Form 10-Q for the quarter ended June 30, 1988 in 1-8474 (Thirty-ninth); A-2(b) to Rule 24 Certificate in 70-7553 (Fortieth); A-2(d) to Rule 24 Certificate in 70-7553 (Forty-first); A-3(a) to Rule 24 Certificate in 70-7822 (Forty-second); A-3(b) to Rule 24 Certificate in 70-7822 (Forty-third); A-2(b) to Rule 24 Certificate in 70-7822 (Forty-fourth); A-3(c) to Rule 24 Certificate in 70-7822 (Forty-fifth); A-2(c) to Rule 24 Certificate dated April 7, 1993 in 70-7822 (Forty-sixth); A-3(d) to Rule 24 Certificate dated June 4, 1993 in 70-7822 (Forth-seventh); A-3(e) to Rule 24 Certificate dated December 21, 1993 in 70-7822 (Forty-eighth); A-3(f) to Rule 24 Certificate dated August 1, 1994 in 70-7822 (Forty-ninth); A-4(c) to Rule 24 Certificate dated September 28, 1994 in 70-7653 (Fiftieth); A-2(a) to Rule 24 Certificate dated April 4, 1996 in 70-8487 (Fifty-first); A-2(a) to Rule 24 Certificate dated April 3, 1998 in 70-9141 (Fifty-second); A-2(b) to Rule 24 Certificate dated April 9, 1999 in 70-9141 (Fifty-third); A-3(a) to Rule 24 Certificate dated July 6, 1999 in 70-9141 (Fifty-fourth); A-2(c) to Rule 24 Certificate dated June 2, 2000 in 70-9141 (Fifty-fifth); A-2(d) to Rule 24 Certificate dated April 4, 2002 in 70-9141 (Fifty-sixth); A-3(a) to Rule 24 Certificate dated March 30, 2004 in 70-10086 (Fifty-seventh); A-3(b) to Rule 24 Certificate dated October 15, 2004 in 70-10086 (Fifty-eighth); A-3(c) to Rule 24 Certificate dated October 26, 2004 in 70-10086 (Fifty-ninth); A-3(d) to Rule 24 Certificate dated May 18, 2005 in 70-10086 (Sixtieth); A-3(e) to Rule 24 Certificate dated August 25, 2005 in 70-10086 (Sixty-first); A-3(f) to Rule 24 Certificate dated October 31, 2005 in 70-10086 (Sixty-second); B-4(i) to Rule 24 Certificate dated January 10, 2006 in 70-10324 (Sixty-third); B-4(ii) to Rule 24 Certificate dated January 10, 2006 in 70-10324 (Sixty-fourth); 4(a) to Form 10-Q for the quarter ended September 30, 2008 in 1-32718 (Sixty-fifth); 4(e)1 to Form 10-K for the year ended December 31, 2009 in 1-132718 (Sixty-sixth); 4(a) to Form 10-Q for the quarter ended March 31, 2010 in 1-32718 (Sixty-seventh); 4.08 to Form 8-K dated September 24, 2010 in 1-32718 (Sixty-eighth); 4(c) to Form 8-K filed October 12, 2010 in 1-32718 (Sixty-ninth); 4.08 to Form 8-K dated November 23, 2010 in 1-32718 (Seventieth); 4.08 to Form 8-K dated March 24, 2011 in 1-32718 (Seventy-first); 4(a) to Form 10-Q for the quarter ended June 30, 2011 in 1-32718 (Seventy-second); 4.08 to Form 8-K dated December 15, 2011 in 1-32718 (Seventy-third); and 4.08 to Form 8-K dated January 12, 2012 in 1-32718 (Seventy-fourth)).

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(e) 2 --	Facility Lease No. 1, dated as of September 1, 1989, between First National Bank of Commerce, as Owner Trustee, and Entergy Louisiana (4(c)-1 in Registration No. 33-30660), as supplemented by Lease Supplement No. 1 dated as of July 1, 1997 (attached to Refunding Agreement No. 1, dated as of June 27, 1997, with such Refunding Agreement filed as Exhibit 2 to Current Report on Form 8-K, dated July 14, 1997 in 1-8474).

(e) 3 --	Facility Lease No. 2, dated as of September 1, 1989, between First National Bank of Commerce, as Owner Trustee, and Entergy Louisiana (4(c)-2 in Registration No. 33-30660), as supplemented by Lease Supplemental No. 1 dated as of July 1, 1997 (attached to Refunding Agreement No. 2, dated as of June 27, 1997, with such Refunding Agreement filed as Exhibit 3 to Current Report on Form 8-K, dated July 14, 1997 in 1-8474).

(e) 4 --	Facility Lease No. 3, dated as of September 1, 1989, between First National Bank of Commerce, as Owner Trustee, and Entergy Louisiana (4(c)-3 in Registration No. 33-30660), as supplemented by Lease Supplemental No. 1 dated as of July 1, 1997 (attached to Refunding Agreement No. 3, dated as of June 27, 1997, with such Refunding Agreement filed as Exhibit 4 to Current Report on Form 8-K, dated July 14, 1997 in 1-8474).

(e) 5 --	Credit Agreement ($200,000,000), dated as of August 2, 2007, among Entergy Louisiana, the Banks (Citibank, N.A., ABN AMRO Bank N.V., Barclays Bank PLC, BNP Paribas, Calyon New York Branch, Credit Suisse (Cayman Islands Branch), JPMorgan Chase Bank, N.A., KeyBank National Association, Mizuho Corporate Bank, Ltd., Morgan Stanley Bank, The Bank of New York, The Royal Bank of Scotland plc, and Wachovia Bank, National Association), Citibank, N.A., as Administrative Agent, and the LC Issuing Banks (10(b) to Form 10-Q for the quarter ended June 30, 2007 in 1-11299).

Entergy Mississippi

(f) 1 --

Mortgage and Deed of Trust, dated as of February 1, 1988, as amended by twenty-nine Supplemental Indentures (A-2(a)-2 to Rule 24 Certificate in 70-7461 (Mortgage); A-2(b)-2 in 70-7461 (First); A-5(b) to Rule 24 Certificate in 70-7419 (Second); A-4(b) to Rule 24 Certificate in 70-7554 (Third); A-1(b)-1 to Rule 24 Certificate in 70-7737 (Fourth); A-2(b) to Rule 24 Certificate dated November 24, 1992 in 70-7914 (Fifth); A-2(e) to Rule 24 Certificate dated January 22, 1993 in 70-7914 (Sixth); A-2(g) to Form U-1 in 70-7914 (Seventh); A-2(i) to Rule 24 Certificate dated November 10, 1993 in 70-7914 (Eighth); A-2(j) to Rule 24 Certificate dated July 22, 1994 in 70-7914 (Ninth); (A-2(l) to Rule 24 Certificate dated April 21, 1995 in 70-7914 (Tenth); A-2(a) to Rule 24 Certificate dated June 27, 1997 in 70-8719 (Eleventh); A-2(b) to Rule 24 Certificate dated April 16, 1998 in 70-8719 (Twelfth); A-2(c) to Rule 24 Certificate dated May 12, 1999 in 70-8719 (Thirteenth); A-3(a) to Rule 24 Certificate dated June 8, 1999 in 70-8719 (Fourteenth); A-2(d) to Rule 24 Certificate dated February 24, 2000 in 70-8719 (Fifteenth); A-2(a) to Rule 24 Certificate dated February 9, 2001 in 70-9757 (Sixteenth); A-2(b) to Rule 24 Certificate dated October 31, 2002 in 70-9757 (Seventeenth); A-2(c) to Rule 24 Certificate dated December 2, 2002 in 70-9757 (Eighteenth); A-2(d) to Rule 24 Certificate dated February 6, 2003 in 70-9757 (Nineteenth); A-2(e) to Rule 24 Certificate dated April 4, 2003 in 70-9757 (Twentieth); A-2(f) to Rule 24 Certificate dated June 6, 2003 in 70-9757 (Twenty-first); A-3(a) to Rule 24 Certificate dated April 8, 2004 in 70-10157 (Twenty-second); A-3(b) to Rule 24 Certificate dated April 29, 2004 in 70-10157 (Twenty-third); A-3(c) to Rule 24 Certificate dated October 4, 2004 in 70-10157 (Twenty-fourth); A-3(d) to Rule 24 Certificate dated January 27, 2006 in 70-10157 (Twenty-fifth); 4(b) to Form 10-Q for the quarter ended June 30, 2009 in 1-31508 (Twenty-sixth); 4(b) to Form 10-Q for the quarter ended March 31, 2010 in 1-31508 (Twenty-seventh); 4.38 to Form 8-K dated April 15, 2011 in 1-31508 (Twenty-eighth); and 4.38 to Form 8-K dated May 13, 2011 in 1-31508 (Twenty-ninth)).

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Entergy New Orleans

(g) 1 --

Mortgage and Deed of Trust, dated as of May 1, 1987, as amended by fifteen Supplemental Indentures (A-2(c) to Rule 24 Certificate in 70-7350 (Mortgage); A-5(b) to Rule 24 Certificate in 70-7350 (First); A-4(b) to Rule 24 Certificate in 70-7448 (Second); 4(f)4 to Form 10-K for the year ended December 31, 1992 in 0-5807 (Third); 4(a) to Form 10-Q for the quarter ended September 30, 1993 in 0-5807 (Fourth); 4(a) to Form 8-K dated April 26, 1995 in 0-5807 (Fifth); 4(a) to Form 8-K dated March 22, 1996 in 0-5807 (Sixth); 4(b) to Form 10-Q for the quarter ended June 30, 1998 in 0-5807 (Seventh); 4(d) to Form 10-Q for the quarter ended June 30, 2000 in 0-5807 (Eighth); C-5(a) to Form U5S for the year ended December 31, 2000 (Ninth); 4(b) to Form 10-Q for the quarter ended September 30, 2002 in 0-5807 (Tenth); 4(k) to Form 10-Q for the quarter ended June 30, 2003 in 0-5807 (Eleventh); 4(a) to Form 10-Q for the quarter ended September 30, 2004 in 0-5807 (Twelfth); 4(b) to Form 10-Q for the quarter ended September 30, 2004 in 0-5807 (Thirteenth); 4(e) to Form 10-Q for the quarter ended June 30, 2005 in 0-5807 (Fourteenth); and 4.02 to Form 8-K dated November 23, 2010 in 0-5807 (Fifteenth)).

Entergy Texas

(h) 1 --	Credit Agreement ($200,000,000), dated as of August 2, 2007, among Entergy Gulf States, Inc. the Banks (Citibank, N.A., ABN AMRO Bank N.V., Barclays Bank PLC, BNP Paribas, Calyon New York Branch, Credit Suisse (Cayman Islands Branch), J. P. Morgan Chase Bank, N.A., KeyBank National Association, Mizuho Corporate Bank, Ltd., Morgan Stanley Bank, The Bank of New York, The Royal Bank of Scotland plc, and Wachovia Bank, National Association), Citibank, N.A., as Administrative Agent and LC Issuing Bank (10(c) to Form 10-Q for the quarter ended June 30, 2007 in 1-11299).

(h) 2 --	Assumption Agreement, dated as of May 30, 2008, among Entergy Texas, Inc., Entergy Gulf States Louisiana, L.L.C. and Citibank, N.A., as administrative agent (10(a) to Form 10-Q for the quarter ended March 31, 2008 in 0-53134).

(h) 3 --	Indenture, Deed of Trust and Security Agreement dated as of October 1, 2008, between Entergy Texas, Inc. and The Bank of New York Mellon, as trustee (4(h)2 to Form 10-K for the year ended December 31, 2008 in 0-53134).

(h) 4 --	Officer’s Certificate No. 1-B-1 dated January 27, 2009, supplemental to Indenture, Deed of Trust and Security Agreement dated as of October 1, 2008, between Entergy Texas, Inc. and The Bank of New York Mellon, as trustee (4(h)3 to Form 10-K for the year ended December 31, 2008 in 0-53134).

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(h) 5 --	Officer’s Certificate No. 2-B-2 dated May 14, 2009, supplemental to Indenture, Deed of Trust and Security Agreement dated as of October 1, 2008, between Entergy Texas, Inc. and The Bank of New York Mellon, as trustee (4(a) to Form 10-Q for the quarter ended June 30, 2009 in 1-34360).

(h) 6 --	Officer’s Certificate No. 3-B-3 dated May 18, 2010, supplemental to Indenture, Deed of Trust and Security Agreement dated as of October 1, 2008, between Entergy Texas, Inc. and The Bank of New York Mellon, as trustee (4(a) to Form 10-Q for the quarter ended June 30, 2010 in 1-34360).

(h) 7 --	Officer’s Certificate No. 5-B-4 dated September 7, 2011, supplemental to Indenture, Deed of Trust and Security Agreement dated as of October 1, 2008, between Entergy Texas, Inc. and The Bank of New York Mellon, as trustee (4.40 to Form 8-K dated September 13, 2011 in 1-34360).

(10) Material Contracts

Entergy Corporation

(a) 1 --	Agreement, dated April 23, 1982, among certain System companies, relating to System Planning and Development and Intra-System Transactions (10(a)1 to Form 10-K for the year ended December 31, 1982 in 1-3517).

(a) 2 --	Second Amended and Restated Entergy System Agency Agreement, dated as of January 1, 2008 (10(a)2 to Form 10-K for the year ended December 31, 2007 in 1-11299).

(a) 3 --	Middle South Utilities System Agency Coordination Agreement, dated December 11, 1970 (5(a)3 in 2-41080).

(a) 4 --	Service Agreement with Entergy Services, dated as of April 1, 1963 (5(a)5 in 2-41080).

(a) 5 --	Amendment, dated April 27, 1984, to Service Agreement with Entergy Services (10(a)7 to Form 10-K for the year ended December 31, 1984 in 1-3517).

(a) 6 --	Amendment, dated January 1, 2000, to Service Agreement with Entergy Services (10(a)12 to Form 10-K for the year ended December 31, 2001 in 1-11299).

*(a) 7 --	Amendment, dated January 1, 2011, to Service Agreement with Entergy Services.

(a) 8 --	Availability Agreement, dated June 21, 1974, among System Energy and certain other System companies (B to Rule 24 Certificate dated June 24, 1974 in 70-5399).

(a) 9 --	First Amendment to Availability Agreement, dated as of June 30, 1977 (B to Rule 24 Certificate dated June 24, 1977 in 70-5399).

(a) 10 --	Second Amendment to Availability Agreement, dated as of June 15, 1981 (E to Rule 24 Certificate dated July 1, 1981 in 70-6592).

(a) 11 --	Third Amendment to Availability Agreement, dated as of June 28, 1984 (B-13(a) to Rule 24 Certificate dated July 6, 1984 in 70-6985).

(a) 12 --	Fourth Amendment to Availability Agreement, dated as of June 1, 1989 (A to Rule 24 Certificate dated June 8, 1989 in 70-5399).

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(a) 13 --	Thirty-fifth Assignment of Availability Agreement, Consent and Agreement, dated as of December 22, 2003, among System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, and Union Bank of California, N.A (10(a)25 to Form 10-K for the year ended December 31, 2003 in 1-11299).

(a) 14 --	First Amendment to Thirty-fifth Assignment of Availability Agreement, Consent and Agreement, dated as of December 17, 2004 (10(a)24 to Form 10-K for the year ended December 31, 2004 in 1-11299).

(a) 15 --	Thirty-sixth Assignment of Availability Agreement, Consent and Agreement, dated as of September 1, 2007, among System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, and The Bank of New York and Douglas J. MacInnes, as trustees (10(a)24 to Form 10-K for the year ended December 31, 2007 in 1-11299).

(a) 16 --	Capital Funds Agreement, dated June 21, 1974, between Entergy Corporation and System Energy (C to Rule 24 Certificate dated June 24, 1974 in 70-5399).

(a) 17 --	First Amendment to Capital Funds Agreement, dated as of June 1, 1989 (B to Rule 24 Certificate dated June 8, 1989 in 70-5399).

(a) 18 --	Thirty-fifth Supplementary Capital Funds Agreement and Assignment, dated as of December 22, 2003, among Entergy Corporation, System Energy, and Union Bank of California, N.A (10(a)38 to Form 10-K for the year ended December 31, 2003 in 1-11299).

(a) 19 --	Thirty-sixth Supplementary Capital Funds Agreement and Assignment, dated as of September 1, 2007, among Entergy Corporation, System Energy and The Bank of New York and Douglas J. MacInnes, as Trustees (10(a)36 to Form 10-K for the year ended December 31, 2007 in 1-11299).

(a) 20 --	First Amendment to Supplementary Capital Funds Agreements and Assignments, dated as of June 1, 1989, by and between Entergy Corporation, System Energy, Deposit Guaranty National Bank, United States Trust Company of New York and Gerard F. Ganey (C to Rule 24 Certificate dated June 8, 1989 in 70-7026).

(a) 21 --	First Amendment to Supplementary Capital Funds Agreements and Assignments, dated as of June 1, 1989, by and between Entergy Corporation, System Energy, United States Trust Company of New York and Gerard F. Ganey (C to Rule 24 Certificate dated June 8, 1989 in 70-7123).

(a) 22 --	First Amendment to Supplementary Capital Funds Agreement and Assignment, dated as of June 1, 1989, by and between Entergy Corporation, System Energy and Chemical Bank (C to Rule 24 Certificate dated June 8, 1989 in 70-7561).

(a) 23 --	Reallocation Agreement, dated as of July 28, 1981, among System Energy and certain other System companies (B-1(a) in 70-6624).

(a) 24 --	Joint Construction, Acquisition and Ownership Agreement, dated as of May 1, 1980, between System Energy and SMEPA (B-1(a) in 70-6337), as amended by Amendment No. 1, dated as of May 1, 1980 (B-1(c) in 70-6337) and Amendment No. 2, dated as of October 31, 1980 (1 to Rule 24 Certificate dated October 30, 1981 in 70-6337).

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(a) 25 --	Operating Agreement dated as of May 1, 1980, between System Energy and SMEPA (B(2)(a) in 70-6337).

(a) 26 --	Assignment, Assumption and Further Agreement No. 1, dated as of December 1, 1988, among System Energy, Meridian Trust Company and Stephen M. Carta, and SMEPA (B-7(c)(1) to Rule 24 Certificate dated January 9, 1989 in 70-7561).

(a) 27 --	Assignment, Assumption and Further Agreement No. 2, dated as of December 1, 1988, among System Energy, Meridian Trust Company and Stephen M. Carta, and SMEPA (B-7(c)(2) to Rule 24 Certificate dated January 9, 1989 in 70-7561).

(a) 28 --	Substitute Power Agreement, dated as of May 1, 1980, among Entergy Mississippi, System Energy and SMEPA (B(3)(a) in 70-6337).

(a) 29 --	Grand Gulf Unit No. 2 Supplementary Agreement, dated as of February 7, 1986, between System Energy and SMEPA (10(aaa) in 33-4033).

(a) 30 --	Compromise and Settlement Agreement, dated June 4, 1982, between Texaco, Inc. and Entergy Louisiana (28(a) to Form 8-K dated June 4, 1982 in 1-3517).

(a) 31 --	Unit Power Sales Agreement, dated as of June 10, 1982, between System Energy and Entergy Arkansas, Entergy Louisiana, Entergy Mississippi and Entergy New Orleans (10(a)39 to Form 10-K for the year ended December 31, 1982 in 1-3517).

(a) 32 --	First Amendment to Unit Power Sales Agreement, dated as of June 28, 1984, between System Energy and Entergy Arkansas, Entergy Louisiana, Entergy Mississippi and Entergy New Orleans (19 to Form 10-Q for the quarter ended September 30, 1984 in 1-3517).

(a) 33 --	Revised Unit Power Sales Agreement (10(ss) in 33-4033).

(a) 34 --	Middle South Utilities Inc. and Subsidiary Companies Intercompany Income Tax Allocation Agreement, dated April 28, 1988 (D-1 to Form U5S for the year ended December 31, 1987).

(a) 35 --	First Amendment, dated January 1, 1990, to the Middle South Utilities Inc. and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-2 to Form U5S for the year ended December 31, 1989).

(a) 36 --	Second Amendment dated January 1, 1992, to the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-3 to Form U5S for the year ended December 31, 1992).

(a) 37 --	Third Amendment dated January 1, 1994 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-3(a) to Form U5S for the year ended December 31, 1993).

(a) 38 --	Fourth Amendment dated April 1, 1997 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-5 to Form U5S for the year ended December 31, 1996).

(a) 39 --	Fifth Amendment dated November 20, 2009 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (10(a)56 to Form 10-K for the year ended December 31, 2009 in 1-11299).

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(a) 40 --	Sixth Amendment dated October 11, 2010 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (10(a) to Form 10-Q for the quarter ended September 30, 2010 in 1-11299).

(a) 41 --	Guaranty Agreement between Entergy Corporation and Entergy Arkansas, dated as of September 20, 1990 (B-1(a) to Rule 24 Certificate dated September 27, 1990 in 70-7757).

(a) 42 --	Guarantee Agreement between Entergy Corporation and Entergy Louisiana, dated as of September 20, 1990 (B-2(a) to Rule 24 Certificate dated September 27, 1990 in 70-7757).

(a) 43 --	Guarantee Agreement between Entergy Corporation and System Energy, dated as of September 20, 1990 (B-3(a) to Rule 24 Certificate dated September 27, 1990 in 70- 7757).

(a) 44 --	Loan Agreement between Entergy Operations and Entergy Corporation, dated as of September 20, 1990 (B-12(b) to Rule 24 Certificate dated June 15, 1990 in 70-7679).

(a) 45 --	Loan Agreement between Entergy Corporation and Entergy Systems and Service, Inc., dated as of December 29, 1992 (A-4(b) to Rule 24 Certificate in 70-7947).

+(a) 46 --	2007 Equity Ownership and Long Term Cash Incentive Plan of Entergy Corporation and Subsidiaries (Effective for Grants and Elections On or After January 1, 2007) (Appendix B to Entergy Corporation’s Definitive Proxy Statement filed on March 24, 2006 in 1-11299).

+(a) 47 --	First Amendment of the 2007 Equity Ownership and Long Term Cash Incentive Plan of Entergy Corporation and Subsidiaries effective October 26, 2006 (10(a)50 to Form 10-K for the year ended December 31, 2010 in 1-11299).

+(a) 48 --	Second Amendment of the 2007 Equity Ownership and Long Term Cash Incentive Plan of Entergy Corporation and Subsidiaries effective January 1, 2009 (10(a)51 to Form 10-K for the year ended December 31, 2010 in 1-11299).

+(a) 49 --	Third Amendment of the 2007 Equity Ownership and Long Term Cash Incentive Plan of Entergy Corporation and Subsidiaries effective December 30, 2010 (10(a)52 to Form 10-K for the year ended December 31, 2010 in 1-11299).

+(a) 50 --	Amended and Restated 1998 Equity Ownership Plan of Entergy Corporation and Subsidiaries (Effective for Grants and Elections After February 13, 2003) (10(a) to Form 10-Q for the quarter ended March 31, 2003 in 1-11299).

+(a) 51 --	First Amendment of the 1998 Equity Ownership Plan of Entergy Corporation and Subsidiaries, effective January 1, 2005 (10(a)54 to Form 10-K for the year ended December 31, 2010 in 1-11299).

+(a) 52 --	Second Amendment of the 1998 Equity Ownership Plan of Entergy Corporation and Subsidiaries, effective October 26, 2006 (10(a)55 to Form 10-K for the year ended December 31, 2010 in 1-11299).

+(a) 53 --	Third Amendment of the 1998 Equity Ownership Plan of Entergy Corporation and Subsidiaries, effective January 1, 2009 (10(a)56 to Form 10-K for the year ended December 31, 2010 in 1-11299).

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+(a) 54 --	2011 Equity Ownership and Long Term Cash Incentive Plan of Entergy Corporation and Subsidiaries (Annex A to Entergy Corporation’s Definitive Proxy Statement filed on March 24, 2011 in 1-11299).

+(a) 55 --	Supplemental Retirement Plan of Entergy Corporation and Subsidiaries, as amended and restated effective January 1, 2009 (10(a)57 to Form 10-K for the year ended December 31, 2010 in 1-11299).

+(a) 56 --	First Amendment of the Supplemental Retirement Plan of Entergy Corporation and Subsidiaries, effective December 30, 2010 (10(a)58 to Form 10-K for the year ended December 31, 2010 in 1-11299).

*+(a) 57 --	Second Amendment of the Supplemental Retirement Plan of Entergy Corporation and Subsidiaries, effective January 27, 2011.

+(a) 58 --	Defined Contribution Restoration Plan of Entergy Corporation and Subsidiaries, as amended and restated effective January 1, 2009 (10(a)59 to Form 10-K for the year ended December 31, 2010 in 1-11299).

+(a) 59 --	First Amendment of the Defined Contribution Restoration Plan of Entergy Corporation and Subsidiaries, effective December 30, 2010 (10(a)60 to Form 10-K for the year ended December 31, 2010 in 1-11299).

*+(a) 60 --	Second Amendment of the Defined Contribution Restoration Plan of Entergy Corporation and Subsidiaries, effective January 27, 2011.

+(a) 61 --	Executive Disability Plan of Entergy Corporation and Subsidiaries (10(a)74 to Form 10-K for the year ended December 31, 2001 in 1-11299).

+(a) 62 --	Executive Deferred Compensation Plan of Entergy Corporation and Subsidiaries, as amended and restated effective January 1, 2009 (10(a)62 to Form 10-K for the year ended December 31, 2010 in 1-11299).

+(a) 63 --	First Amendment of the Executive Deferred Compensation Plan of Entergy Corporation and Subsidiaries, effective December 30, 2010 (10(a)63 to Form 10-K for the year ended December 31, 2010 in 1-11299).

*+(a) 64 --	Second Amendment of the Executive Deferred Compensation Plan of Entergy Corporation and Subsidiaries, effective January 27, 2011.

+(a) 65 --	Equity Awards Plan of Entergy Corporation and Subsidiaries, effective as of August 31, 2000 (10(a)77 to Form 10-K for the year ended December 31, 2001 in 1-11299).

+(a) 66 --	Amendment, effective December 7, 2001, to the Equity Awards Plan of Entergy Corporation and Subsidiaries (10(a)78 to Form 10-K for the year ended December 31, 2001 in 1-11299).

+(a) 67 --	Amendment, effective December 10, 2001, to the Equity Awards Plan of Entergy Corporation and Subsidiaries (10(b) to Form 10-Q for the quarter ended March 31, 2002 in 1-11299).

+(a) 68 --	System Executive Continuity Plan of Entergy Corporation and Subsidiaries, effective as of January 1, 2009 (10(a)77 to Form 10-K for the year ended December 31, 2009 in 1-11299).

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+(a) 69--	First Amendment of the System Executive Continuity Plan of Entergy Corporation and Subsidiaries, effective January 1, 2010 (10(a)78 to Form 10-K for the year ended December 31, 2009 in 1-11299).

+(a) 70 --	Second Amendment of the System Executive Continuity Plan of Entergy Corporation and Subsidiaries, effective December 30, 2010 (10(a)69 to Form 10-K for the year ended December 31, 2010 in 1-11299).

*+(a) 71 --	Third Amendment of the System Executive Continuity Plan of Entergy Corporation and Subsidiaries, effective January 27, 2011.

+(a) 72 --	Post-Retirement Plan of Entergy Corporation and Subsidiaries, as amended effective January 1, 2000 (10(a)80 to Form 10-K for the year ended December 31, 2001 in 1-11299).

+(a) 73 --	Amendment, effective December 28, 2001, to the Post-Retirement Plan of Entergy Corporation and Subsidiaries (10(a)81 to Form 10-K for the year ended December 31, 2001 in 1-11299).

+(a) 74 --	Pension Equalization Plan of Entergy Corporation and Subsidiaries, as amended and restated effective January 1, 2009 (10(a)74 to Form 10-K for the year ended December 31, 2010 in 1-11299).

+(a) 75 --	First Amendment of the Pension Equalization Plan of Entergy Corporation and Subsidiaries, effective December 30, 2010 (10(a)75 to Form 10-K for the year ended December 31, 2010 in 1-11299).

*+(a) 76 --	Second Amendment of the Pension Equalization Plan of Entergy Corporation and Subsidiaries, effective January 27, 2011.

+(a) 77 --	Service Recognition Program for Non-Employee Outside Directors of Entergy Corporation and Subsidiaries, effective January 1, 2009 (10(a) to Form 10-Q for the quarter ended June 30, 2008 in 1-11299).

+(a) 78 --	Executive Income Security Plan of Gulf States Utilities Company, as amended effective March 1, 1991 (10(a)86 to Form 10-K for the year ended December 31, 2001 in 1-11299).

+(a) 79 --	System Executive Retirement Plan of Entergy Corporation and Subsidiaries, effective January 1, 2009 (10(a)78 to Form 10-K for the year ended December 31, 2010 in 1-11299).

+(a) 80 --	First Amendment of the System Executive Retirement Plan of Entergy Corporation and Subsidiaries, effective December 30, 2010 (10(a)79 to Form 10-K for the year ended December 31, 2010 in 1-11299).

*+(a) 81 --	Second Amendment of the System Executive Retirement Plan of Entergy Corporation and Subsidiaries, effective January 27, 2011.

+(a) 82 --	Retention Agreement effective October 27, 2000 between J. Wayne Leonard and Entergy Corporation (10(a)81 to Form 10-K for the year ended December 31, 2000 in 1-11299).

+(a) 83 --	Amendment to Retention Agreement effective March 8, 2004 between J. Wayne Leonard and Entergy Corporation (10(c) to Form 10-Q for the quarter ended March 31, 2004 in 1-11299).

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+(a) 84 --	Amendment to Retention Agreement effective December 30, 2005 between J. Wayne Leonard and Entergy Corporation (10(a)91 to Form 10-K for the year ended December 31, 2005 in 1-11299).

+(a) 85 --	Amendment to Retention Agreement effective January 1, 2009 between J. Wayne Leonard and Entergy Corporation (10(a)83 to Form 10-K for the year ended December 31, 2010 in 1-11299).

+(a) 86 --	Amendment to Retention Agreement effective January 1, 2010 between J. Wayne Leonard and Entergy Corporation (10(a)92 to Form 10-K for the year ended December 31, 2009 in 1-11299).

+(a) 87 --	Amendment to Retention Agreement effective December 30, 2010 between J. Wayne Leonard and Entergy Corporation (10(a)85 to Form 10-K for the year ended December 31, 2010 in 1-11299).

+(a) 88 --	Restricted Unit Agreement between J. Wayne Leonard and Entergy Corporation (10(a)93 to Form 10-K for the year ended December 31, 2009 in 1-11299).

(a) 89 --	Agreement of Limited Partnership of Entergy-Koch, LP among EKLP, LLC, EK Holding I, LLC, EK Holding II, LLC and Koch Energy, Inc. dated January 31, 2001 (10(a)94 to Form 10-K/A for the year ended December 31, 2000 in 1-11299).

+(a) 90 --	Employment Agreement effective November 24, 2003 between Mark T. Savoff and Entergy Services (10(a)99 to Form 10-K for the year ended December 31, 2003 in 1-11299).

+(a) 91 --	Employment Agreement effective February 9, 1999 between Leo P. Denault and Entergy Services (10(a) to Form 10-Q for the quarter ended March 31, 2004 in 1-11299).

+(a) 92 --	Amendment to Employment Agreement effective March 5, 2004 between Leo P. Denault and Entergy Corporation (10(b) to Form 10-Q for the quarter ended March 31, 2004 in 1-11299).

+(a) 93 --	Retention Agreement effective August 3, 2006 between Leo P. Denault and Entergy Corporation (10(b) to Form 10-Q for the quarter ended June 30, 2006 in 1-11299).

+(a) 94 --	Amendment to Retention Agreement effective January 1, 2009 between Leo P. Denault and Entergy Corporation (10(a)93 to Form 10-K for the year ended December 31, 2010 in 1-11299).

+(a) 95 --	Amendment to Retention Agreement effective January 1, 2010 between Leo P. Denault and Entergy Corporation (10(a)101 to Form 10-K for the year ended December 31, 2009 in 1-11299).

+(a) 96 --	Amendment to Retention Agreement effective December 30, 2010 between Leo P. Denault and Entergy Corporation (10(a)95 to Form 10-K for the year ended December 31, 2010 in 1-11299).

+(a) 97 --	Shareholder Approval of Future Severance Agreements Policy, effective March 8, 2004 (10(f) to Form 10-Q for the quarter ended March 31, 2004 in 1-11299).

+(a) 98 --	Entergy Corporation Outside Director Stock Program Established under the 2007 Equity Ownership and Long Term Cash Incentive Plan of Entergy Corporation and Subsidiaries (Amended and Restated effective January 1, 2009) (10(b) to Form 10-Q for the quarter ended June 30, 2008 in 1-11299).

+(a) 99 --	First Amendment to Entergy Corporation Outside Director Stock Program Established under the 2007 Equity Ownership and Long Term Cash Incentive Plan of Entergy Corporation Subsidiaries (10(a)105 to Form 10-K for the year ended December 31, 2008 in 1-11299).

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+(a) 100 --	Entergy Corporation Outside Director Stock Program Established under the 2011 Equity Ownership and Long Term Cash Incentive Plan of Entergy Corporation and Subsidiaries (10(b) to Form 10-Q for the quarter ended June 30, 2011 in 1-11299).

+(a) 101 --	Rescission Agreement effective July 26, 2007 between Richard J. Smith and Entergy Services, Inc. (10(d) to Form 10-Q for the quarter ended June 30, 2007 in 1-11299).

+(a) 102 --	Entergy Nuclear Retention Plan, as amended and restated January 1, 2007 (10(a)107 to Form 10-K for the year ended December 31, 2007 in 1-11299).

+(a) 103 --	Restricted Unit Agreement between Leo P. Denault and Entergy Corporation (10(a) to Form 10-Q for the quarter ended March 31, 2008 in 1-11299).

+(a) 104 --	Retention Agreement effective December 16, 2009 between Richard J. Smith and Entergy Corporation (10(a)112 to Form 10-K for the year ended December 31, 2009 in 1-11299).

+(a) 105 --	Executive Annual Incentive Plan of Entergy Corporation and Subsidiaries as amended and restated effective January 1, 2010 (Annex A to Entergy Corporation’s Definitive Proxy Statement filed on March 17, 2010 in 1-11299).

*+(a) 106 --	First Amendment of the Executive Annual Incentive Plan of Entergy Corporation and Subsidiaries, effective January 27, 2011.

*+(a) 107 --	Form of Stock Option Grant Letter.

*+(a) 108 --	Form of Long Term Incentive Program Performance Unit Grant Letter.

*+(a) 109 --	Form of Restricted Stock Grant Letter.

(a) 110 --	Employee Matters Agreement, dated as of December 4, 2011, among Entergy Corporation, Mid South TransCo LLC and ITC Holdings Corp. (10.1 to Form 8-K filed December 6, 2011 in 1-11299).

System Energy

(b) 1 through (b) 8 -- See 10(a)8 through 10(a)15 above.

(b) 9 through (b) 15 -- See 10(a)16 through 10(a)22 above.

(b) 16 --	Reallocation Agreement, dated as of July 28, 1981, among System Energy and certain other System companies (B-1(a) in 70-6624).

(b) 17 --	Joint Construction, Acquisition and Ownership Agreement, dated as of May 1, 1980, between System Energy and SMEPA (B-1(a) in 70-6337), as amended by Amendment No. 1, dated as of May 1, 1980 (B-1(c) in 70-6337) and Amendment No. 2, dated as of October 31, 1980 (1 to Rule 24 Certificate dated October 30, 1981 in 70-6337).

(b) 18 --	Operating Agreement, dated as of May 1, 1980, between System Energy and SMEPA (B(2)(a) in 70-6337).

(b) 19 --	Amended and Restated Installment Sale Agreement, dated as of February 15, 1996, between System Energy and Claiborne County, Mississippi (B-6(a) to Rule 24 Certificate dated March 4, 1996 in 70-8511).

(b) 20 --	Loan Agreement, dated as of October 15, 1998, between System Energy and Mississippi Business Finance Corporation (B-6(b) to Rule 24 Certificate dated November 12, 1998 in 70-8511).

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(b) 21 --	Loan Agreement, dated as of May 15, 1999, between System Energy and Mississippi Business Finance Corporation (B-6(c) to Rule 24 Certificate dated June 8, 1999 in 70-8511).

(b) 22 --	Facility Lease No. 1, dated as of December 1, 1988, between Meridian Trust Company and Stephen M. Carta (Stephen J. Kaba, successor), as Owner Trustees, and System Energy (B-2(c)(1) to Rule 24 Certificate dated January 9, 1989 in 70-7561), as supplemented by Lease Supplement No. 1 dated as of April 1, 1989 (B-22(b) (1) to Rule 24 Certificate dated April 21, 1989 in 70-7561), Lease Supplement No. 2 dated as of January 1, 1994 (B-3(d) to Rule 24 Certificate dated January 31, 1994 in 70-8215), and Lease Supplement No. 3 dated as of May 1, 2004 (B-3(d) to Rule 24 Certificate dated June 4, 2004 in 70-10182).

(b) 23 --	Facility Lease No. 2, dated as of December 1, 1988 between Meridian Trust Company and Stephen M. Carta (Stephen J. Kaba, successor), as Owner Trustees, and System Energy (B-2(c)(2) to Rule 24 Certificate dated January 9, 1989 in 70-7561), as supplemented by Lease Supplement No. 1 dated as of April 1, 1989 (B-22(b) (2) to Rule 24 Certificate dated April 21, 1989 in 70-7561), Lease Supplement No. 2 dated as of January 1, 1994 (B-4(d) Rule 24 Certificate dated January 31, 1994 in 70-8215), and Lease Supplement No. 3 dated as of May 1, 2004 (B-4(d) to Rule 24 Certificate dated June 4, 2004 in 70-10182).

(b) 24 --	Assignment, Assumption and Further Agreement No. 1, dated as of December 1, 1988, among System Energy, Meridian Trust Company and Stephen M. Carta, and SMEPA (B-7(c)(1) to Rule 24 Certificate dated January 9, 1989 in 70-7561).

(b) 25 --	Assignment, Assumption and Further Agreement No. 2, dated as of December 1, 1988, among System Energy, Meridian Trust Company and Stephen M. Carta, and SMEPA (B-7(c)(2) to Rule 24 Certificate dated January 9, 1989 in 70-7561).

(b) 26 --	Collateral Trust Indenture, dated as of May 1, 2004, among GG1C Funding Corporation, System Energy, and Deutsche Bank Trust Company Americas, as Trustee (A-3(a) to Rule 24 Certificate dated June 4, 2004 in 70-10182), as supplemented by Supplemental Indenture No. 1 dated May 1, 2004, (A-4(a) to Rule 24 Certificate dated June 4, 2004 in 70-10182).

(b) 27 --	Substitute Power Agreement, dated as of May 1, 1980, among Entergy Mississippi, System Energy and SMEPA (B(3)(a) in 70-6337).

(b) 28 --	Grand Gulf Unit No. 2 Supplementary Agreement, dated as of February 7, 1986, between System Energy and SMEPA (10(aaa) in 33-4033).

(b) 29 --	Unit Power Sales Agreement, dated as of June 10, 1982, between System Energy and Entergy Arkansas, Entergy Louisiana, Entergy Mississippi and Entergy New Orleans (10(a)39 to Form 10-K for the year ended December 31, 1982 in 1-3517).

(b) 30 --	First Amendment to the Unit Power Sales Agreement, dated as of June 28, 1984, between System Energy and Entergy Arkansas, Entergy Louisiana, Entergy Mississippi and Entergy New Orleans (19 to Form 10-Q for the quarter ended September 30, 1984 in 1-3517).

(b) 31 --	Revised Unit Power Sales Agreement (10(ss) in 33-4033).

(b) 32 --	Fuel Lease, dated as of February 24, 1989, between River Fuel Funding Company #3, Inc. and System Energy (B-1(b) to Rule 24 Certificate dated March 3, 1989 in 70-7604).

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(b) 33 --	System Energy’s Consent, dated January 31, 1995, pursuant to Fuel Lease, dated as of February 24, 1989, between River Fuel Funding Company #3, Inc. and System Energy (B-1(c) to Rule 24 Certificate dated February 13, 1995 in 70-7604).

(b) 34 --	Sales Agreement, dated as of June 21, 1974, between System Energy and Entergy Mississippi (D to Rule 24 Certificate dated June 26, 1974 in 70-5399).

(b) 35 --	Service Agreement, dated as of June 21, 1974, between System Energy and Entergy Mississippi (E to Rule 24 Certificate dated June 26, 1974 in 70-5399).

(b) 36 --	Partial Termination Agreement, dated as of December 1, 1986, between System Energy and Entergy Mississippi (A-2 to Rule 24 Certificate dated January 8, 1987 in 70-5399).

(b) 37 --	Middle South Utilities, Inc. and Subsidiary Companies Intercompany Income Tax Allocation Agreement, dated April 28, 1988 (D-1 to Form U5S for the year ended December 31, 1987).

(b) 38 --	First Amendment, dated January 1, 1990 to the Middle South Utilities Inc. and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-2 to Form U5S for the year ended December 31, 1989).

(b) 39 --	Second Amendment dated January 1, 1992, to the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-3 to Form U5S for the year ended December 31, 1992).

(b) 40 --	Third Amendment dated January 1, 1994 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-3(a) to Form U5S for the year ended December 31, 1993).

(b) 41 --	Fourth Amendment dated April 1, 1997 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-5 to Form U5S for the year ended December 31, 1996).

(b) 42 --	Fifth Amendment dated November 20, 2009 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (10(a)56 to Form 10-K for the year ended December 31, 2009 in 1-9067).

(b) 43 --	Sixth Amendment dated October 11, 2010 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (10(a) to Form 10-Q for the quarter ended September 30, 2010 in 1-9067).

(b) 44 --	Service Agreement with Entergy Services, dated as of July 16, 1974, as amended (10(b)43 to Form 10-K for the year ended December 31, 1988 in 1-9067).

(b) 45 --	Amendment, dated January 1, 2004, to Service Agreement with Entergy Services (10(b)57 to Form 10-K for the year ended December 31, 2004 in 1-9067).

*(b) 46 --	Amendment, dated January 1, 2011, to Service Agreement with Entergy Services.

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(b) 47 --	Operating Agreement between Entergy Operations and System Energy, dated as of June 6, 1990 (B-3(b) to Rule 24 Certificate dated June 15, 1990 in 70-7679).

(b) 48 --	Guarantee Agreement between Entergy Corporation and System Energy, dated as of September 20, 1990 (B-3(a) to Rule 24 Certificate dated September 27, 1990 in 70-7757).

(b) 49 --	Letter of Credit and Reimbursement Agreement, dated as of December 22, 2003, among System Energy Resources, Inc., Union Bank of California, N.A., as administrating bank and funding bank, Keybank National Association, as syndication agent, Banc One Capital Markets, Inc., as documentation agent, and the Banks named therein, as Participating Banks (10(b)63 to Form 10-K for the year ended December 31, 2003 in 1-9067).

(b) 50 --	Amendment to Letter of Credit and Reimbursement Agreement, dated as of December 22, 2003 (10(b)62 to Form 10-K for the year ended December 31, 2004 in 1-9067).

(b) 51 --	First Amendment and Consent, dated as of May 3, 2004, to Letter of Credit and Reimbursement Agreement (10(b)63 to Form 10-K for the year ended December 31, 2004 in 1-9067).

(b) 52 --	Second Amendment and Consent, dated as of December 17, 2004, to Letter of Credit and Reimbursement Agreement (99 to Form 8-K dated December 22, 2004 in 1-9067).

(b) 53 --	Third Amendment and Consent, dated as of May 14, 2009, to Letter of Credit and Reimbursement Agreement (10(b)69 to Form 10-K for the year ended December 31, 2009 in 1-9067).

(b) 54 --	Fourth Amendment and Consent, dated as of April 15, 2010, to Letter of Credit and Reimbursement Agreement (10(a) to Form 10-Q for the quarter ended March 31, 2010 in 1-9067).

Entergy Arkansas

(c) 1 --	Agreement, dated April 23, 1982, among Entergy Arkansas and certain other System companies, relating to System Planning and Development and Intra-System Transactions (10(a) 1 to Form 10-K for the year ended December 31, 1982 in 1-3517).

(c) 2 --	Second Amended and Restated Entergy System Agency Agreement, dated as of January 1, 2008 (10(a)2 to Form 10-K for the year ended December 31, 2007 in 1-10764).

(c) 3 --	Middle South Utilities System Agency Coordination Agreement, dated December 11, 1970 (5(a)3 in 2-41080).

(c) 4 --	Service Agreement with Entergy Services, dated as of April 1, 1963 (5(a)5 in 2-41080).

(c) 5 --	Amendment, dated April 27, 1984, to Service Agreement, with Entergy Services (10(a)7 to Form 10-K for the year ended December 31, 1984 in 1-3517).

(c) 6 --	Amendment, dated January 1, 2000, to Service Agreement with Entergy Services (10(a)12 to Form 10-K for the year ended December 31, 2002 in 1-10764).

*(c) 7 --	Amendment, dated January 1, 2011, to Service Agreement with Entergy Services.

(c) 8 through (c) 15 -- See 10(a)8 through 10(a)15 above.

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(c) 16 --	Agreement, dated August 20, 1954, between Entergy Arkansas and the United States of America (SPA)(13(h) in 2-11467).

(c) 17 --	Amendment, dated April 19, 1955, to the United States of America (SPA) Contract, dated August 20, 1954 (5(d)2 in 2-41080).

(c) 18 --	Amendment, dated January 3, 1964, to the United States of America (SPA) Contract, dated August 20, 1954 (5(d)3 in 2-41080).

(c) 19 --	Amendment, dated September 5, 1968, to the United States of America (SPA) Contract, dated August 20, 1954 (5(d)4 in 2-41080).

(c) 20 --	Amendment, dated November 19, 1970, to the United States of America (SPA) Contract, dated August 20, 1954 (5(d)5 in 2-41080).

(c) 21 --	Amendment, dated July 18, 1961, to the United States of America (SPA) Contract, dated August 20, 1954 (5(d)6 in 2-41080).

(c) 22 --	Amendment, dated December 27, 1961, to the United States of America (SPA) Contract, dated August 20, 1954 (5(d)7 in 2-41080).

(c) 23 --	Amendment, dated January 25, 1968, to the United States of America (SPA) Contract, dated August 20, 1954 (5(d)8 in 2-41080).

(c) 24 --	Amendment, dated October 14, 1971, to the United States of America (SPA) Contract, dated August 20, 1954 (5(d)9 in 2-43175).

(c) 25 --	Amendment, dated January 10, 1977, to the United States of America (SPA) Contract, dated August 20, 1954 (5(d)10 in 2-60233).

(c) 26 --	Agreement, dated May 14, 1971, between Entergy Arkansas and the United States of America (SPA) (5(e) in 2-41080).

(c) 27 --	Amendment, dated January 10, 1977, to the United States of America (SPA) Contract, dated May 14, 1971 (5(e)1 in 2-60233).

(c) 28 --	Contract, dated May 28, 1943, Amendment to Contract, dated July 21, 1949, and Supplement to Amendment to Contract, dated December 30, 1949, between Entergy Arkansas and McKamie Gas Cleaning Company; Agreements, dated as of September 30, 1965, between Entergy Arkansas and former stockholders of McKamie Gas Cleaning Company; and Letter Agreement, dated June 22, 1966, by Humble Oil & Refining Company accepted by Entergy Arkansas on June 24, 1966 (5(k)7 in 2-41080).

(c) 29 --	Fuel Lease, dated as of December 22, 1988, between River Fuel Trust #1 and Entergy Arkansas (B-1(b) to Rule 24 Certificate in 70-7571).

(c) 30 --	White Bluff Operating Agreement, dated June 27, 1977, among Entergy Arkansas and Arkansas Electric Cooperative Corporation and City Water and Light Plant of the City of Jonesboro, Arkansas (B-2(a) to Rule 24 Certificate dated June 30, 1977 in 70-6009).

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(c) 31 --	White Bluff Ownership Agreement, dated June 27, 1977, among Entergy Arkansas and Arkansas Electric Cooperative Corporation and City Water and Light Plant of the City of Jonesboro, Arkansas (B-1(a) to Rule 24 Certificate dated June 30, 1977 in 70-6009).

(c) 32 --	Agreement, dated June 29, 1979, between Entergy Arkansas and City of Conway, Arkansas (5(r)3 in 2-66235).

(c) 33 --	Transmission Agreement, dated August 2, 1977, between Entergy Arkansas and City Water and Light Plant of the City of Jonesboro, Arkansas (5(r)3 in 2-60233).

(c) 34 --	Power Coordination, Interchange and Transmission Service Agreement, dated as of June 27, 1977, between Arkansas Electric Cooperative Corporation and Entergy Arkansas (5(r)4 in 2-60233).

(c) 35 --	Independence Steam Electric Station Operating Agreement, dated July 31, 1979, among Entergy Arkansas and Arkansas Electric Cooperative Corporation and City Water and Light Plant of the City of Jonesboro, Arkansas and City of Conway, Arkansas (5(r)6 in 2-66235).

(c) 36 --	Amendment, dated December 4, 1984, to the Independence Steam Electric Station Operating Agreement (10(c)51 to Form 10-K for the year ended December 31, 1984 in 1-10764).

(c) 37 --	Independence Steam Electric Station Ownership Agreement, dated July 31, 1979, among Entergy Arkansas and Arkansas Electric Cooperative Corporation and City Water and Light Plant of the City of Jonesboro, Arkansas and City of Conway, Arkansas (5(r)7 in 2-66235).

(c) 38 --	Amendment, dated December 28, 1979, to the Independence Steam Electric Station Ownership Agreement (5(r)7(a) in 2-66235).

(c) 39 --	Amendment, dated December 4, 1984, to the Independence Steam Electric Station Ownership Agreement (10(c)54 to Form 10-K for the year ended December 31, 1984 in 1-10764).

(c) 40 --	Owner’s Agreement, dated November 28, 1984, among Entergy Arkansas, Entergy Mississippi, other co-owners of the Independence Station (10(c)55 to Form 10-K for the year ended December 31, 1984 in 1-10764).

(c) 41 --	Consent, Agreement and Assumption, dated December 4, 1984, among Entergy Arkansas, Entergy Mississippi, other co-owners of the Independence Station and United States Trust Company of New York, as Trustee (10(c)56 to Form 10-K for the year ended December 31, 1984 in 1-10764).

(c) 42 --	Power Coordination, Interchange and Transmission Service Agreement, dated as of July 31, 1979, between Entergy Arkansas and City Water and Light Plant of the City of Jonesboro, Arkansas (5(r)8 in 2-66235).

(c) 43 --	Power Coordination, Interchange and Transmission Agreement, dated as of June 29, 1979, between City of Conway, Arkansas and Entergy Arkansas (5(r)9 in 2-66235).

(c) 44 --	Agreement, dated June 21, 1979, between Entergy Arkansas and Reeves E. Ritchie (10(b)90 to Form 10-K for the year ended December 31, 1980 in 1-10764).

(c) 45 --	Reallocation Agreement, dated as of July 28, 1981, among System Energy and certain other System companies (B-1(a) in 70-6624).

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(c) 46 --	Unit Power Sales Agreement, dated as of June 10, 1982, between System Energy and Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans (10(a)39 to Form 10-K for the year ended December 31, 1982 in 1-3517).

(c) 47 --	First Amendment to Unit Power Sales Agreement, dated as of June 28, 1984, between System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans (19 to Form 10-Q for the quarter ended September 30, 1984 in 1-3517).

(c) 48 --	Revised Unit Power Sales Agreement (10(ss) in 33-4033).

(c) 49 --	Contract For Disposal of Spent Nuclear Fuel and/or High-Level Radioactive Waste, dated June 30, 1983, among the DOE, System Fuels and Entergy Arkansas (10(b)57 to Form 10-K for the year ended December 31, 1983 in 1-10764).

(c) 50 --	Middle South Utilities, Inc. and Subsidiary Companies Intercompany Income Tax Allocation Agreement, dated April 28, 1988 (D-1 to Form U5S for the year ended December 31, 1987).

(c) 51 --	First Amendment, dated January 1, 1990, to the Middle South Utilities, Inc. and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-2 to Form U5S for the year ended December 31, 1989).

(c) 52 --	Second Amendment dated January 1, 1992, to the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-3 to Form U5S for the year ended December 31, 1992).

(c) 53 --	Third Amendment dated January 1, 1994, to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-3(a) to Form U5S for the year ended December 31, 1993).

(c) 54 --	Fourth Amendment dated April 1, 1997 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-5 to Form U5S for the year ended December 31, 1996).

(c) 55 --	Fifth Amendment dated November 20, 2009 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (10(a)56 to Form 10-K for the year ended December 31, 2009 in 1-10764).

(c) 56 --	Sixth Amendment dated October 11, 2010 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (10(a) to Form 10-Q for the quarter ended September 30, 2010 in 1-10764).

(c) 57 --	Assignment of Coal Supply Agreement, dated December 1, 1987, between System Fuels and Entergy Arkansas (B to Rule 24 letter filing dated November 10, 1987 in 70-5964).

(c) 58 --	Coal Supply Agreement, dated December 22, 1976, between System Fuels and Antelope Coal Company (B-1 in 70-5964), as amended by First Amendment (A to Rule 24 Certificate in 70-5964); Second Amendment (A to Rule 24 letter filing dated December 16, 1983 in 70-5964); and Third Amendment (A to Rule 24 letter filing dated November 10, 1987 in 70-5964).

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(c) 59 --	Operating Agreement between Entergy Operations and Entergy Arkansas, dated as of June 6, 1990 (B-1(b) to Rule 24 Certificate dated June 15, 1990 in 70-7679).

(c) 60 --	Guaranty Agreement between Entergy Corporation and Entergy Arkansas, dated as of September 20, 1990 (B-1(a) to Rule 24 Certificate dated September 27, 1990 in 70-7757).

(c) 61 --	Agreement for Purchase and Sale of Independence Unit 2 between Entergy Arkansas and Entergy Power, dated as of August 28, 1990 (B-3(c) to Rule 24 Certificate dated September 6, 1990 in 70-7684).

(c) 62 --	Agreement for Purchase and Sale of Ritchie Unit 2 between Entergy Arkansas and Entergy Power, dated as of August 28, 1990 (B-4(d) to Rule 24 Certificate dated September 6, 1990 in 70-7684).

(c) 63 --	Ritchie Steam Electric Station Unit No. 2 Operating Agreement between Entergy Arkansas and Entergy Power, dated as of August 28, 1990 (B-5(a) to Rule 24 Certificate dated September 6, 1990 in 70-7684).

(c) 64 --	Ritchie Steam Electric Station Unit No. 2 Ownership Agreement between Entergy Arkansas and Entergy Power, dated as of August 28, 1990 (B-6(a) to Rule 24 Certificate dated September 6, 1990 in 70-7684).

(c) 65 --	Power Coordination, Interchange and Transmission Service Agreement between Entergy Power and Entergy Arkansas, dated as of August 28, 1990 (10(c)71 to Form 10-K for the year ended December 31, 1990 in 1-10764).

Entergy Gulf States Louisiana

(d) 1 --	Agreement effective February 1, 1964, between Sabine River Authority, State of Louisiana, and Sabine River Authority of Texas, and Entergy Gulf States, Inc., Central Louisiana Electric Company, Inc., and Louisiana Power & Light Company, as supplemented (B to Form 8-K dated May 6, 1964, A to Form 8-K dated October 5, 1967, A to Form 8-K dated May 5, 1969, and A to Form 8-K dated December 1, 1969 in 1-27031).

(d) 2 --	Joint Ownership Participation and Operating Agreement regarding River Bend Unit 1 Nuclear Plant, dated August 20, 1979, between Entergy Gulf States, Inc., Cajun, and SRG&T; Power Interconnection Agreement with Cajun, dated June 26, 1978, and approved by the REA on August 16, 1979, between Entergy Gulf States, Inc. and Cajun; and Letter Agreement regarding CEPCO buybacks, dated August 28, 1979, between Entergy Gulf States, Inc. and Cajun (2, 3, and 4, respectively, to Form 8-K dated September 7, 1979 in 1-27031).

(d) 3 --	Lease Agreement, dated September 18, 1980, between BLC Corporation and Entergy Gulf States, Inc. (1 to Form 8-K dated October 6, 1980 in 1-27031).

(d) 4 --	Joint Ownership Participation and Operating Agreement for Big Cajun, between Entergy Gulf States, Inc., Cajun Electric Power Cooperative, Inc., and Sam Rayburn G&T, Inc, dated November 14, 1980 (6 to Form 8-K dated January 29, 1981 in 1-27031); Amendment No. 1, dated December 12, 1980 (7 to Form 8-K dated January 29, 1981 in 1-27031); Amendment No. 2, dated December 29, 1980 (8 to Form 8-K dated January 29, 1981 in 1-27031).

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(d) 5 --	Agreement of Joint Ownership Participation between SRMPA, SRG&T and Entergy Gulf States, Inc., dated June 6, 1980, for Nelson Station, Coal Unit #6, as amended (8 to Form 8-K dated June 11, 1980, A-2-b to Form 10-Q for the quarter ended June 30, 1982; and 10-1 to Form 8-K dated February 19, 1988 in 1-27031).

(d) 6 --	Agreements between Southern Company and Entergy Gulf States, Inc., dated February 25, 1982, which cover the construction of a 140-mile transmission line to connect the two systems, purchase of power and use of transmission facilities (10-31 to Form 10-K for the year ended December 31, 1981 in 1-27031).

(d) 7 --	Transmission Facilities Agreement between Entergy Gulf States, Inc. and Mississippi Power Company, dated February 28, 1982, and Amendment, dated May 12, 1982 (A-2-c to Form 10-Q for the quarter ended March 31, 1982 in 1-27031) and Amendment, dated December 6, 1983 (10-43 to Form 10-K for the year ended December 31, 1983 in 1-27031).

(d) 8 --	First Amended Power Sales Agreement, dated December 1, 1985 between Sabine River Authority, State of Louisiana, and Sabine River Authority, State of Texas, and Entergy Gulf States, Inc., Central Louisiana Electric Co., Inc., and Louisiana Power and Light Company (10-72 to Form 10-K for the year ended December 31, 1985 in 1-27031).

+(d) 9 --	Deferred Compensation Plan for Directors of Entergy Gulf States, Inc. and Varibus Corporation, as amended January 8, 1987, and effective January 1, 1987 (10-77 to Form 10-K for the year ended December 31, 1986 in 1-27031). Amendment dated December 4, 1991 (10-3 to Amendment No. 8 in Registration No. 2-76551).

+(d) 10 --	Trust Agreement for Deferred Payments to be made by Entergy Gulf States, Inc. pursuant to the Executive Income Security Plan, by and between Entergy Gulf States, Inc. and Bankers Trust Company, effective November 1, 1986 (10-78 to Form 10-K for the year ended December 31, 1986 in 1-27031).

+(d) 11 --	Trust Agreement for Deferred Installments under Entergy Gulf States, Inc. Management Incentive Compensation Plan and Administrative Guidelines by and between Entergy Gulf States, Inc. and Bankers Trust Company, effective June 1, 1986 (10-79 to Form 10-K for the year ended December 31, 1986 in 1-27031).

+(d) 12 --	Nonqualified Deferred Compensation Plan for Officers, Nonemployee Directors and Designated Key Employees, effective December 1, 1985, as amended, continued and completely restated effective as of March 1, 1991 (10-3 to Amendment No. 8 in Registration No. 2-76551).

+(d) 13 --	Trust Agreement for Entergy Gulf States, Inc. Nonqualified Directors and Designated Key Employees by and between Entergy Gulf States, Inc. and First City Bank, Texas-Beaumont, N.A. (now Texas Commerce Bank), effective July 1, 1991 (10-4 to Form 10-K for the year ended December 31, 1992 in 1-27031).

(d) 14 --	Nuclear Fuel Lease Agreement between Entergy Gulf States, Inc. and River Bend Fuel Services, Inc. to lease the fuel for River Bend Unit 1, dated February 7, 1989 (10-64 to Form 10-K for the year ended December 31, 1988 in 1-27031).

(d) 15 --	Trust and Investment Management Agreement between Entergy Gulf States, Inc. and Morgan Guaranty and Trust Company of New York (the “Decommissioning Trust Agreement”) with respect to decommissioning funds authorized to be collected by Entergy Gulf States, Inc., dated March 15, 1989 (10-66 to Form 10-K for the year ended December 31, 1988 in 1-27031).

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(d) 16 --	Amendment No. 2 dated November 1, 1995 between Entergy Gulf States, Inc. and Mellon Bank to Decommissioning Trust Agreement (10(d)31 to Form 10-K for the year ended December 31, 1995 in 1-27031).

(d) 17 --	Amendment No. 3 dated March 5, 1998 between Entergy Gulf States, Inc. and Mellon Bank to Decommissioning Trust Agreement (10(d)23 to Form 10-K for the year ended December 31, 2004 in 1-27031).

(d) 18 --	Amendment No. 4 dated December 17, 2003 between Entergy Gulf States, Inc. and Mellon Bank to Decommissioning Trust Agreement (10(d)24 to Form 10-K for the year ended December 31, 2004 in 1-27031).

(d) 19 --	Amendment No. 5 dated December 31, 2007 between Entergy Gulf States Louisiana, L.L.C. and Mellon Bank. N.A. to Decommissioning Trust Agreement (10(d)21 to Form 10-K for the year ended December 31, 2007 in 333-148557).

(d) 20 --	Partnership Agreement by and among Conoco Inc., and Entergy Gulf States, Inc., CITGO Petroleum Corporation and Vista Chemical Company, dated April 28, 1988 (10-67 to Form 10-K for the year ended December 31, 1988 in 1-27031).

+(d) 21 --	Gulf States Utilities Company Executive Continuity Plan, dated January 18, 1991 (10-6 to Form 10-K for the year ended December 31, 1990 in 1-27031).

+(d) 22 --	Trust Agreement for Entergy Gulf States, Inc. Executive Continuity Plan, by and between Entergy Gulf States, Inc. and First City Bank, Texas-Beaumont, N.A. (now Texas Commerce Bank), effective May 20, 1991 (10-5 to Form 10-K for the year ended December 31, 1992 in 1-27031).

+(d) 23 --	Gulf States Utilities Board of Directors’ Retirement Plan, dated February 15, 1991 (10-8 to Form 10-K for the year ended December 31, 1990 in 1-27031).

(d) 24 --	Third Amendment, dated January 1, 1994, to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-3(a) to Form U5S for the year ended December 31, 1993).

(d) 25 --	Fourth Amendment, dated April 1, 1997, to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-5 to Form U5S for the year ended December 31, 1996).

(d) 26 --	Fifth Amendment dated November 20, 2009 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (10(a)56 to Form 10-K for the year ended December 31, 2009 in 0-20371).

(d) 27 --	Sixth Amendment dated October 11, 2010 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (10(a) to Form 10-Q for the quarter ended September 30, 2010 in 0-20371).

(d) 28 --	Operating Agreement dated as of January 1, 2008, between Entergy Operations, Inc. and Entergy Gulf States Louisiana (10(d)39 to Form 10-K for the year ended December 31, 2007 in 333-148557).

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(d) 29 --	Service Agreement dated as of January 1, 2008, between Entergy Services, Inc. and Entergy Gulf States Louisiana (10(d)40 to Form 10-K for the year ended December 31, 2007 in 333-148557).

*(d) 30 --	Amendment, dated January 1, 2011, to Service Agreement with Entergy Services.

(d) 31 --	Second Amended and Restated Entergy System Agency Agreement, dated as of January 1, 2008 (10(a)2 to Form 10-K for the year ended December 31, 2007 in 333-148557).

(d) 32 --	Decommissioning Trust Agreement, dated as of December 22, 1997, by and between Cajun Electric Power Cooperative, Inc. and Mellon Bank, N.A. with respect to decommissioning funds authorized to be collected by Cajun Electric Power Cooperative, Inc. and related Settlement Term Sheet (10(d)42 to Form 10-K for the year ended December 31, 2007 in 333-148557).

(d) 33 --	First Amendment to Decommissioning Trust Agreement, dated as of December 23, 2003, by and among Cajun Electric Power Cooperative, Inc., Mellon Bank, N.A., Entergy Gulf States, Inc., and the Rural Utilities Services of the United States Department of Agriculture (10(d)43 to Form 10-K for the year ended December 31, 2007 in 333-148557).

(d) 34 --	Second Amendment to Decommissioning Trust Agreement, dated December 31, 2007, by and among Cajun Electric Power Cooperative, Inc., Mellon Bank, N.A., Entergy Gulf States Louisiana, L.L.C., and the Rural Utilities Services of the United States Department of Agriculture (10(d)44 to Form 10-K for the year ended December 31, 2007 in 333-148557).

(d) 35 --	Second Amended and Restated Limited Liability Company Agreement of Entergy Holdings Company LLC dated as of July 22, 2010 (10(a) to Form 10-Q for the quarter ended June 30, 2010).

(d) 36 --	Loan Agreement, dated as of October 1, 2010, between the Louisiana Public Facilities Authority and Entergy Gulf States Louisiana, L.L.C. relating to Revenue Bonds (Entergy Gulf States Louisiana, L.L.C. Project) Series 2010A (4(b) to Form 8-K filed October 12, 2010 in 0-20371).

(d) 37 --	Loan Agreement, dated as of October 1, 2010, between the Louisiana Public Facilities Authority and Entergy Gulf States Louisiana, L.L.C. relating to Revenue Bonds (Entergy Gulf States Louisiana, L.L.C. Project) Series 2010B (4(e) to Form 8-K filed October 12, 2010 in 0-20371).

Entergy Louisiana

(e) 1 --	Agreement, dated April 23, 1982, among Entergy Louisiana and certain other System companies, relating to System Planning and Development and Intra-System Transactions (10(a)1 to Form 10-K for the year ended December 31, 1982, in 1-3517).

(e) 2 --	Second Amended and Restated Entergy System Agency Agreement, dated as of January 1, 2008 (10(a)2 to Form 10-K for the year ended December 31, 2007 in 1-32718).

(e) 3 --	Middle South Utilities System Agency Coordination Agreement, dated December 11, 1970 (5(a)3 in 2-41080).

(e) 4 --	Service Agreement with Entergy Services, dated as of April 1, 1963 (5(a)5 in 2-42523).

(e) 5 --	Amendment, dated as of April 27, 1984, to Service Agreement with Entergy Services (10(a)7 to Form 10-K for the year ended December 31, 1984 in 1-3517).

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(e) 6 --	Amendment, dated January 1, 2000, to Service Agreement with Entergy Services (10(e)12 to Form 10-K for the year ended December 31, 2002 in 1-8474).

*(e) 7 --	Amendment, dated January 1, 2011, to Service Agreement with Entergy Services.

(e) 8 through (e) 15 -- See 10(a)8 through 10(a)15 above.

(e) 16 --	Fuel Lease, dated as of January 31, 1989, between River Fuel Company #2, Inc., and Entergy Louisiana (B-1(b) to Rule 24 Certificate in 70-7580).

(e) 17 --	Reallocation Agreement, dated as of July 28, 1981, among System Energy and certain other System companies (B-1(a) in 70-6624).

(e) 18 --	Compromise and Settlement Agreement, dated June 4, 1982, between Texaco, Inc. and Entergy Louisiana (28(a) to Form 8-K dated June 4, 1982 in 1-8474).

(e) 19 --	Unit Power Sales Agreement, dated as of June 10, 1982, between System Energy and Entergy Arkansas, Entergy Louisiana, Entergy Mississippi and Entergy New Orleans (10(a)39 to Form 10-K for the year ended December 31, 1982 in 1-3517).

(e) 20 --	First Amendment to the Unit Power Sales Agreement, dated as of June 28, 1984, between System Energy and Entergy Arkansas, Entergy Louisiana, Entergy Mississippi and Entergy New Orleans (19 to Form 10-Q for the quarter ended September 30, 1984 in 1-3517).

(e) 21 --	Revised Unit Power Sales Agreement (10(ss) in 33-4033).

(e) 22 --	Contract for Disposal of Spent Nuclear Fuel and/or High-Level Radioactive Waste, dated February 2, 1984, among DOE, System Fuels and Entergy Louisiana (10(d)33 to Form 10-K for the year ended December 31, 1984 in 1-8474).

(e) 23--	Operating Agreement between Entergy Operations and Entergy Louisiana, dated as of June 6, 1990 (B-2(c) to Rule 24 Certificate dated June 15, 1990 in 70-7679).

(e) 24 --	Guarantee Agreement between Entergy Corporation and Entergy Louisiana, dated as of September 20, 1990 (B-2(a) to Rule 24 Certificate dated September 27, 1990 in 70-7757).

(e) 25 --	Second Amended and Restated Limited Liability Company Agreement of Entergy Holdings Company LLC dated as of July 22, 2010 (10(a) to Form 10-Q for the quarter ended June 30, 2010).

(e) 26 --	Fifth Amendment dated November 20, 2009 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (10(a)56 to Form 10-K for the year ended December 31, 2009 in 1-32718).

(e) 27 --	Sixth Amendment dated October 11, 2010 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (10(a) to Form 10-Q for the quarter ended September 30, 2010 in 1-32718).

(e) 28 --	Loan Agreement, dated as of October 1, 2010, between the Louisiana Public Facilities Authority and Entergy Louisiana, LLC relating to Revenue Bonds (Entergy Louisiana, LLC Project) Series 2010 (4(b) to Form 8-K filed October 12, 2010 in 1-32718).

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Entergy Mississippi

(f) 1 --	Agreement dated April 23, 1982, among Entergy Mississippi and certain other System companies, relating to System Planning and Development and Intra-System Transactions (10(a)1 to Form 10-K for the year ended December 31, 1982 in 1-3517).

(f) 2 --	Second Amended and Restated Entergy System Agency Agreement, dated as of January 1, 2008 (10(a)2 to Form 10-K for the year ended December 31, 2007 in 1-31508).

(f) 3 --	Middle South Utilities System Agency Coordination Agreement, dated December 11, 1970 (5(a)3 in 2-41080).

(f) 4 --	Service Agreement with Entergy Services, dated as of April 1, 1963 (D in 37-63).

(f) 5 --	Amendment, dated April 27, 1984, to Service Agreement with Entergy Services (10(a)7 to Form 10-K for the year ended December 31, 1984 in 1-3517).

(f) 6 --	Amendment, dated January 1, 2000, to Service Agreement with Entergy Services (10(f)12 to Form 10-K for the year ended December 31, 2002 in 1-31508).

*(f) 7 --	Amendment, dated January 1, 2011, to Service Agreement with Entergy Services.

(f) 8 through (f) 15 -- See 10(a)8 through 10(a)15 above.

(f) 16 --	Loan Agreement, dated as of September 1, 2004, between Entergy Mississippi and Mississippi Business Finance Corporation (B-3(a) to Rule 24 Certificate dated October 4, 2004 in 70-10157).

(f) 17 --	Refunding Agreement, dated as of May 1, 1999, between Entergy Mississippi and Independence County, Arkansas (B-6(a) to Rule 24 Certificate dated June 8, 1999 in 70-8719).

(f) 18 --	Substitute Power Agreement, dated as of May 1, 1980, among Entergy Mississippi, System Energy and SMEPA (B-3(a) in 70-6337).

(f) 19 --	Amendment, dated December 4, 1984, to the Independence Steam Electric Station Operating Agreement (10(c)51 to Form 10-K for the year ended December 31, 1984 in 0-375).

(f) 20 --	Amendment, dated December 4, 1984, to the Independence Steam Electric Station Ownership Agreement (10(c)54 to Form 10-K for the year ended December 31, 1984 in 0-375).

(f) 21 --	Owners Agreement, dated November 28, 1984, among Entergy Arkansas, Entergy Mississippi and other co-owners of the Independence Station (10(c)55 to Form 10-K for the year ended December 31, 1984 in 0-375).

(f) 22 --	Consent, Agreement and Assumption, dated December 4, 1984, among Entergy Arkansas, Entergy Mississippi, other co-owners of the Independence Station and United States Trust Company of New York, as Trustee (10(c)56 to Form 10-K for the year ended December 31, 1984 in 0-375).

(f) 23 --	Reallocation Agreement, dated as of July 28, 1981, among System Energy and certain other System companies (B-1(a) in 70-6624).

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+(f) 24 --	Post-Retirement Plan (10(d)24 to Form 10-K for the year ended December 31, 1983 in 0-320).

(f) 25 --	Unit Power Sales Agreement, dated as of June 10, 1982, between System Energy and Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans (10(a)39 to Form 10-K for the year ended December 31, 1982 in 1-3517).

(f) 26 --	First Amendment to the Unit Power Sales Agreement, dated as of June 28, 1984, between System Energy and Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans (19 to Form 10-Q for the quarter ended September 30, 1984 in 1-3517).

(f) 27 --	Revised Unit Power Sales Agreement (10(ss) in 33-4033).

(f) 28 --	Sales Agreement, dated as of June 21, 1974, between System Energy and Entergy Mississippi (D to Rule 24 Certificate dated June 26, 1974 in 70-5399).

(f) 29 --	Service Agreement, dated as of June 21, 1974, between System Energy and Entergy Mississippi (E to Rule 24 Certificate dated June 26, 1974 in 70-5399).

(f) 30 --	Partial Termination Agreement, dated as of December 1, 1986, between System Energy and Entergy Mississippi (A-2 to Rule 24 Certificate dated January 8, 1987 in 70-5399).

(f) 31 --	Middle South Utilities, Inc. and Subsidiary Companies Intercompany Income Tax Allocation Agreement, dated April 28, 1988 (D-1 to Form U5S for the year ended December 31, 1987).

(f) 32 --	First Amendment dated January 1, 1990 to the Middle South Utilities Inc. and Subsidiary Companies Intercompany Tax Allocation Agreement (D-2 to Form U5S for the year ended December 31, 1989).

(f) 33 --	Second Amendment dated January 1, 1992, to the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-3 to Form U5S for the year ended December 31, 1992).

(f) 34 --	Third Amendment dated January 1, 1994 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-3(a) to Form U5S for the year ended December 31, 1993).

(f) 35 --	Fourth Amendment dated April 1, 1997 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-5 to Form U5S for the year ended December 31, 1996).

(f) 36 --	Fifth Amendment dated November 20, 2009 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (10(a)56 to Form 10-K for the year ended December 31, 2009 in 1-31508).

(f) 37 --	Sixth Amendment dated October 11, 2010 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (10(a) to Form 10-Q for the quarter ended September 30, 2010 in 1-31508).

(f) 38 --	Purchase and Sale Agreement by and between Central Mississippi Generating Company, LLC and Entergy Mississippi, Inc., dated as of March 16, 2005 (10(b) to Form 10-Q for the quarter ended March 31, 2005 in 1-31508).

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Entergy New Orleans

(g) 1 --	Agreement, dated April 23, 1982, among Entergy New Orleans and certain other System companies, relating to System Planning and Development and Intra-System Transactions (10(a)1 to Form 10-K for the year ended December 31, 1982 in 1-3517).

(g) 2 --	Second Amended and Restated Entergy System Agency Agreement, dated as of January 1, 2008 (10(a)2 to Form 10-K for the year ended December 31, 2007 in 0-5807).

(g) 3 --	Middle South Utilities System Agency Coordination Agreement, dated December 11, 1970 (5(a)3 in 2-41080).

(g) 4 --	Service Agreement with Entergy Services dated as of April 1, 1963 (5(a)5 in 2-42523).

(g) 5 --	Amendment, dated as of April 27, 1984, to Service Agreement with Entergy Services (10(a)7 to Form 10-K for the year ended December 31, 1984 in 1-3517).

(g) 6 --	Amendment, dated January 1, 2000, to Service Agreement with Entergy Services (10(g)12 to Form 10-K for the year ended December 31, 2002 in 0-5807).

*(g) 7 --	Amendment, dated January 1, 2011, to Service Agreement with Entergy Services.

(g) 8 through (g) 15 -- See 10(a)8 through 10(a)15 above.

(g) 16 --	Reallocation Agreement, dated as of July 28, 1981, among System Energy and certain other System companies (B-1(a) in 70-6624).

(g) 17 --	Unit Power Sales Agreement, dated as of June 10, 1982, between System Energy and Entergy Arkansas, Entergy Louisiana, Entergy Mississippi and Entergy New Orleans (10(a)39 to Form 10-K for the year ended December 31, 1982 in 1-3517).

(g) 18 --	First Amendment to the Unit Power Sales Agreement, dated as of June 28, 1984, between System Energy and Entergy Arkansas, Entergy Louisiana, Entergy Mississippi and Entergy New Orleans (19 to Form 10-Q for the quarter ended September 30, 1984 in 1-3517).

(g) 19 --	Revised Unit Power Sales Agreement (10(ss) in 33-4033).

(g) 20 --	Transfer Agreement, dated as of June 28, 1983, among the City of New Orleans, Entergy New Orleans and Regional Transit Authority (2(a) to Form 8-K dated June 24, 1983 in 1-1319).

(g) 21 --	Middle South Utilities, Inc. and Subsidiary Companies Intercompany Income Tax Allocation Agreement, dated April 28, 1988 (D-1 to Form U5S for the year ended December 31, 1987).

(g) 22 --	First Amendment, dated January 1, 1990, to the Middle South Utilities, Inc. and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-2 to Form U5S for the year ended December 31, 1989).

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(g) 23 --	Second Amendment dated January 1, 1992, to the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-3 to Form U5S for the year ended December 31, 1992).

(g) 24 --	Third Amendment dated January 1, 1994 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-3(a) to Form U5S for the year ended December 31, 1993).

(g) 25 --	Fourth Amendment dated April 1, 1997 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-5 to Form U5S for the year ended December 31, 1996).

(g) 26 --	Fifth Amendment dated November 20, 2009 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (10(a)56 to Form 10-K for the year ended December 31, 2009 in 0-5807).

(g) 27 --	Sixth Amendment dated October 11, 2010 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (10(a) to Form 10-Q for the quarter ended September 30, 2010 in 0-5807).

(g) 28 --	Chapter 11 Plan of Reorganization of Entergy New Orleans, Inc., as modified, dated May 2, 2007, confirmed by bankruptcy court order dated May 7, 2007 (2(a) to Form 10-Q for the quarter ended March 31, 2007 in 0-5807).

Entergy Texas

(h) 1 --	Agreement effective February 1, 1964, between Sabine River Authority, State of Louisiana, and Sabine River Authority of Texas, and Entergy Gulf States, Inc., Central Louisiana Electric Company, Inc., and Louisiana Power & Light Company, as supplemented (B to Form 8-K dated May 6, 1964, A to Form 8-K dated October 5, 1967, A to Form 8-K dated May 5, 1969, and A to Form 8-K dated December 1, 1969 in 1-27031).

(h) 2 --	Ground Lease, dated August 15, 1980, between Statmont Associates Limited Partnership (Statmont) and Entergy Gulf States, Inc., as amended (3 to Form 8-K dated August 19, 1980 and A-3-b to Form 10-Q for the quarter ended September 30, 1983 in 1-27031).

(h) 3 --	Lease and Sublease Agreement, dated August 15, 1980, between Statmont and Entergy Gulf States, Inc., as amended (4 to Form 8-K dated August 19, 1980 and A-3-c to Form 10-Q for the quarter ended September 30, 1983 in 1-27031).

(h) 4 --	Lease Agreement, dated September 18, 1980, between BLC Corporation and Entergy Gulf States, Inc. (1 to Form 8-K dated October 6, 1980 in 1-27031).

(h) 5 --	Joint Ownership Participation and Operating Agreement for Big Cajun, between Entergy Gulf States, Inc., Cajun Electric Power Cooperative, Inc., and Sam Rayburn G&T, Inc, dated November 14, 1980 (6 to Form 8-K dated January 29, 1981 in 1-27031); Amendment No. 1, dated December 12, 1980 (7 to Form 8-K dated January 29, 1981 in 1-27031); Amendment No. 2, dated December 29, 1980 (8 to Form 8-K dated January 29, 1981 in 1-27031).

(h) 6 --	Agreement of Joint Ownership Participation between SRMPA, SRG&T and Entergy Gulf States, Inc., dated June 6, 1980, for Nelson Station, Coal Unit #6, as amended (8 to Form 8-K dated June 11, 1980, A-2-b to Form 10-Q for the quarter ended June 30, 1982; and 10-1 to Form 8-K dated February 19, 1988 in 1-27031).

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(h) 7 --	First Amended Power Sales Agreement, dated December 1, 1985 between Sabine River Authority, State of Louisiana, and Sabine River Authority, State of Texas, and Entergy Gulf States, Inc., Central Louisiana Electric Co., Inc., and Louisiana Power and Light Company (10-72 to Form 10-K for the year ended December 31, 1985 in 1-27031).

+(h) 8 --	Deferred Compensation Plan for Directors of Entergy Gulf States, Inc. and Varibus Corporation, as amended January 8, 1987, and effective January 1, 1987 (10-77 to Form 10-K for the year ended December 31, 1986 in 1-27031). Amendment dated December 4, 1991 (10-3 to Amendment No. 8 in Registration No. 2-76551).

+(h) 9 --	Trust Agreement for Deferred Payments to be made by Entergy Gulf States, Inc. pursuant to the Executive Income Security Plan, by and between Entergy Gulf States, Inc. and Bankers Trust Company, effective November 1, 1986 (10-78 to Form 10-K for the year ended December 31, 1986 in 1-27031).

+(h) 10 --	Trust Agreement for Deferred Installments under Entergy Gulf States, Inc. Management Incentive Compensation Plan and Administrative Guidelines by and between Entergy Gulf States, Inc. and Bankers Trust Company, effective June 1, 1986 (10-79 to Form 10-K for the year ended December 31, 1986 in 1-27031).

+(h) 11 --	Nonqualified Deferred Compensation Plan for Officers, Nonemployee Directors and Designated Key Employees, effective December 1, 1985, as amended, continued and completely restated effective as of March 1, 1991 (10-3 to Amendment No. 8 in Registration No. 2-76551).

+(h) 12 --	Trust Agreement for Entergy Gulf States, Inc. Nonqualified Directors and Designated Key Employees by and between Entergy Gulf States, Inc. and First City Bank, Texas-Beaumont, N.A. (now Texas Commerce Bank), effective July 1, 1991 (10-4 to Form 10-K for the year ended December 31, 1992 in 1-27031).

(h) 13 --	Lease Agreement, dated as of June 29, 1987, among GSG&T, Inc., and Entergy Gulf States, Inc. related to the leaseback of the Lewis Creek generating station (10-83 to Form 10-K for the year ended December 31, 1988 in 1-27031).

+(h) 14 --	Gulf States Utilities Company Executive Continuity Plan, dated January 18, 1991 (10-6 to Form 10-K for the year ended December 31, 1990 in 1-27031).

+(h) 15 --	Trust Agreement for Entergy Gulf States, Inc. Executive Continuity Plan, by and between Entergy Gulf States, Inc. and First City Bank, Texas-Beaumont, N.A. (now Texas Commerce Bank), effective May 20, 1991 (10-5 to Form 10-K for the year ended December 31, 1992 in 1-27031).

+(h) 16 --	Gulf States Utilities Board of Directors’ Retirement Plan, dated February 15, 1991 (10-8 to Form 10-K for the year ended December 31, 1990 in 1-27031).

(h) 17 --	Third Amendment, dated January 1, 1994, to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-3(a) to Form U5S for the year ended December 31, 1993).

(h) 18 --	Fourth Amendment, dated April 1, 1997, to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (D-5 to Form U5S for the year ended December 31, 1996).

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(h) 19 --	Fifth Amendment dated November 20, 2009 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (10(a)56 to Form 10-K for the year ended December 31, 2009 in 1-34360).

(h) 20 --	Sixth Amendment dated October 11, 2010 to Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement (10(a) to Form 10-Q for the quarter ended September 30, 2010 in 1-34360).

(h) 21 --	Service Agreement dated as of January 1, 2008, between Entergy Services, Inc. and Entergy Texas (10(h)25 to Form 10-K for the year ended December 31, 2008 in 3-53134).

*(h) 22 --	Amendment, dated January 1, 2011, to Service Agreement with Entergy Services.

(12) Statement Re Computation of Ratios

*(a)	Entergy Arkansas’s Computation of Ratios of Earnings to Fixed Charges and of Earnings to Fixed Charges and Preferred Dividends, as defined.

*(b)	Entergy Gulf States Louisiana’s Computation of Ratios of Earnings to Fixed Charges and of Earnings to Fixed Charges and Preferred Distributions, as defined.

*(c)	Entergy Louisiana’s Computation of Ratios of Earnings to Fixed Charges and of Earnings to Fixed Charges and Preferred Distributions, as defined.

*(d)	Entergy Mississippi’s Computation of Ratios of Earnings to Fixed Charges and of Earnings to Fixed Charges and Preferred Dividends, as defined.

*(e)	Entergy New Orleans’s Computation of Ratios of Earnings to Fixed Charges and of Earnings to Fixed Charges and Preferred Dividends, as defined.

*(f)	Entergy Texas’s Computation of Ratios of Earnings to Fixed Charges, as defined.

*(g)	System Energy’s Computation of Ratios of Earnings to Fixed Charges, as defined.

*(21) Subsidiaries of the Registrants

(23) Consents of Experts and Counsel

*(a)	The consent of Deloitte & Touche LLP is contained herein at page 492.

*(24) Powers of Attorney

(31) Rule 13a-14(a)/15d-14(a) Certifications

*(a)	Rule 13a-14(a)/15d-14(a) Certification for Entergy Corporation.

*(b)	Rule 13a-14(a)/15d-14(a) Certification for Entergy Corporation.

*(c)	Rule 13a-14(a)/15d-14(a) Certification for Entergy Arkansas.

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*(d)	Rule 13a-14(a)/15d-14(a) Certification for Entergy Arkansas.

*(e)	Rule 13a-14(a)/15d-14(a) Certification for Entergy Gulf States Louisiana.

*(f)	Rule 13a-14(a)/15d-14(a) Certification for Entergy Gulf States Louisiana.

*(g)	Rule 13a-14(a)/15d-14(a) Certification for Entergy Louisiana.

*(h)	Rule 13a-14(a)/15d-14(a) Certification for Entergy Louisiana.

*(i)	Rule 13a-14(a)/15d-14(a) Certification for Entergy Mississippi.

*(j)	Rule 13a-14(a)/15d-14(a) Certification for Entergy Mississippi.

*(k)	Rule 13a-14(a)/15d-14(a) Certification for Entergy New Orleans.

*(l)	Rule 13a-14(a)/15d-14(a) Certification for Entergy New Orleans.

*(m)	Rule 13a-14(a)/15d-14(a) Certification for Entergy Texas.

*(n)	Rule 13a-14(a)/15d-14(a) Certification for Entergy Texas.

*(o)	Rule 13a-14(a)/15d-14(a) Certification for System Energy.

*(p)	Rule 13a-14(a)/15d-14(a) Certification for System Energy.

(32) Section 1350 Certifications

*(a)	Section 1350 Certification for Entergy Corporation.

*(b)	Section 1350 Certification for Entergy Corporation.

*(c)	Section 1350 Certification for Entergy Arkansas.

*(d)	Section 1350 Certification for Entergy Arkansas.

*(e)	Section 1350 Certification for Entergy Gulf States Louisiana.

*(f)	Section 1350 Certification for Entergy Gulf States Louisiana.

*(g)	Section 1350 Certification for Entergy Louisiana.

*(h)	Section 1350 Certification for Entergy Louisiana.

*(i)	Section 1350 Certification for Entergy Mississippi.

*(j)	Section 1350 Certification for Entergy Mississippi.

*(k)	Section 1350 Certification for Entergy New Orleans.

E-34

Table of Contents

*(l)	Section 1350 Certification for Entergy New Orleans.

*(m)	Section 1350 Certification for Entergy Texas.

*(n)	Section 1350 Certification for Entergy Texas.

*(o)	Section 1350 Certification for System Energy.

*(p)	Section 1350 Certification for System Energy.

(101) XBRL Documents

Entergy Corporation

*INS -	XBRL Instance Document.

*SCH -	XBRL Taxonomy Extension Schema Document.

*CAL -	XBRL Taxonomy Extension Calculation Linkbase Document.

*DEF -	XBRL Taxonomy Extension Definition Linkbase Document.

*LAB -	XBRL Taxonomy Extension Label Linkbase Document.

*PRE -	XBRL Taxonomy Extension Presentation Linkbase Document.

_________________

* Filed herewith.

+ Management contracts or compensatory plans or arrangements.

E-35

Pension Asset Allocation	Target	Range	2011	2010

Domestic Equity Securities	45%	34% to 53%	44%	44%
International Equity Securities	20%	16% to 24%	18%	20%
Fixed Income Securities	35%	31% to 41%	37%	35%
Other	0%	0% to 10%	1%	1%

Postretirement Asset Allocation	Non-Taxable				Taxable
	Target	Range	2011	2010	Target	Range	2011	2010
Domestic Equity Securities	38%	33% to 43%	39%	39%	35%	30% to 40%	35%	39%
International Equity Securities	17%	12% to 22%	15%	18%	0%	0%	0%	0%
Fixed Income Securities	45%	40% to 50%	46%	43%	65%	60% to 70%	64%	60%
Other	0%	0% to 5%	0%	0%	0%	0% to 5%	1%	1%