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__________________________________________________________________________________________

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)
☑			QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2021

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						1-35747			ENTERGY NEW ORLEANS, LLC
			(a Delaware corporation) 639 Loyola Avenue New Orleans, Louisiana 70113 Telephone (504) 576-4000									(a Texas limited liability company) 1600 Perdido Street New Orleans, Louisiana 70112 Telephone (504) 670-3700
			72-1229752									82-2212934
1-10764			ENTERGY ARKANSAS, LLC						1-34360			ENTERGY TEXAS, INC.
			(a Texas limited liability company) 425 West Capitol Avenue Little Rock, Arkansas 72201 Telephone (501) 377-4000									(a Texas corporation) 10055 Grogans Mill Road The Woodlands, Texas 77380 Telephone (409) 981-2000
			83-1918668									61-1435798
1-32718			ENTERGY LOUISIANA, LLC						1-09067			SYSTEM ENERGY RESOURCES, INC.
			(a Texas limited liability company) 4809 Jefferson Highway Jefferson, Louisiana 70121 Telephone (504) 576-4000									(an Arkansas corporation) 1340 Echelon Parkway Jackson, Mississippi 39213 Telephone (601) 368-5000
			47-4469646									72-0752777
1-31508			ENTERGY MISSISSIPPI, LLC
			(a Texas limited liability company) 308 East Pearl Street Jackson, Mississippi 39201 Telephone (601) 368-5000
			83-1950019

__________________________________________________________________________________________

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

Registrant			Title of Class			Trading Symbol			Name of Each Exchange on Which Registered
Entergy Corporation			Common Stock, $0.01 Par Value			ETR			New York Stock Exchange
			Common Stock, $0.01 Par Value			ETR			NYSE Chicago, Inc.
Entergy Arkansas, LLC			Mortgage Bonds, 4.875% Series due September 2066			EAI			New York Stock Exchange
Entergy Louisiana, LLC			Mortgage Bonds, 4.875% Series due September 2066			ELC			New York Stock Exchange
Entergy Mississippi, LLC			Mortgage Bonds, 4.90% Series due October 2066			EMP			New York Stock Exchange
Entergy New Orleans, LLC			Mortgage Bonds, 5.0% Series due December 2052			ENJ			New York Stock Exchange
			Mortgage Bonds, 5.50% Series due April 2066			ENO			New York Stock Exchange
Entergy Texas, Inc.			5.375% Series A Preferred Stock, Cumulative, No Par Value (Liquidation Value $25 Per Share)			ETI/PR			New York Stock Exchange

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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 ☑ No ☐

Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted 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 registrants were required to submit such files).  Yes ☑ No ☐

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

Large accelerated filer

Accelerated filer

Non-accelerated filer

Smaller reporting company

Emerging growth company

Entergy Corporation

ü

Entergy Arkansas, LLC

ü

Entergy Louisiana, LLC

ü

Entergy Mississippi, LLC

ü

Entergy New Orleans, LLC

ü

Entergy Texas, Inc.

ü

System Energy Resources, Inc.

ü

If an emerging growth company, indicate by check mark if the registrants have elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

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

Common Stock Outstanding						Outstanding at July 30, 2021
Entergy Corporation			($0.01 par value)			200,954,557

Entergy Corporation, Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, Entergy New Orleans, LLC, Entergy Texas, Inc., and System Energy Resources, Inc. separately file this combined Quarterly Report on Form 10-Q.  Information contained herein relating to any individual company is filed by such company on its own behalf.  Each company reports herein only as to itself and makes no other representations whatsoever as to any other company.  This combined Quarterly Report on Form 10-Q supplements and updates the Annual Report on Form 10-K for the calendar year ended December 31, 2020 and the Quarterly Report on Form 10-Q for the quarter ended March 31, 2021, filed by the individual registrants with the SEC, and should be read in conjunction therewith.

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TABLE OF CONTENTS

			Page Number
Forward-looking Information			iii
Definitions			v
Part I. Financial Information
Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis			1
Consolidated Income Statements			22
Consolidated Statements of Comprehensive Income			23
Consolidated Statements of Cash Flows			24
Consolidated Balance Sheets			26
Consolidated Statements of Changes in Equity			28
Notes to Financial Statements
Note 1. Commitments and Contingencies			30
Note 2. Rate and Regulatory Matters			31
Note 3. Equity			42
Note 4. Revolving Credit Facilities, Lines of Credit, Short-term Borrowings, and Long-term Debt			50
Note 5. Stock-based Compensation			54
Note 6. Retirement and Other Postretirement Benefits			56
Note 7. Business Segment Information			64
Note 8. Risk Management and Fair Values			66
Note 9. Decommissioning Trust Funds			84
Note 10. Income Taxes			91
Note 11. Property, Plant, and Equipment			91
Note 12. Variable Interest Entities			92
Note 13. Revenue			92
Note 14. Acquisitions and Dispositions			96
Item 3. Quantitative and Qualitative Disclosures About Market Risk			97
Item 4. Controls and Procedures			97
Entergy Arkansas, LLC and Subsidiaries
Management’s Financial Discussion and Analysis			98
Consolidated Income Statements			108
Consolidated Statements of Cash Flows			109
Consolidated Balance Sheets			110
Consolidated Statements of Changes in Member’s Equity			112
Entergy Louisiana, LLC and Subsidiaries
Management’s Financial Discussion and Analysis			113
Consolidated Income Statements			125

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			Page Number
Consolidated Statements of Comprehensive Income			126
Consolidated Statements of Cash Flows			127
Consolidated Balance Sheets			128
Consolidated Statements of Changes in Equity			130
Entergy Mississippi, LLC
Management’s Financial Discussion and Analysis			131
Income Statements			140
Statements of Cash Flows			141
Balance Sheets			142
Statements of Changes in Member’s Equity			144
Entergy New Orleans, LLC and Subsidiaries
Management’s Financial Discussion and Analysis			145
Consolidated Income Statements			154
Consolidated Statements of Cash Flows			155
Consolidated Balance Sheets			156
Consolidated Statements of Changes in Member’s Equity			158
Entergy Texas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis			159
Consolidated Income Statements			170
Consolidated Statements of Cash Flows			171
Consolidated Balance Sheets			172
Consolidated Statements of Changes in Equity			174
System Energy Resources, Inc.
Management’s Financial Discussion and Analysis			175
Income Statements			182
Statements of Cash Flows			183
Balance Sheets			184
Statements of Changes in Common Equity			186
Part II. Other Information
Item 1. Legal Proceedings			187
Item 1A. Risk Factors			187
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds			188
Item 5. Other Information			188
Item 6. Exhibits			191
Signature			194

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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, projections, 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 in the Form 10-K and in this report, (b) Management’s Financial Discussion and Analysis in the Form 10-K and in this report, 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 related litigation, formula rate proceedings and related negotiations, including various performance-based rate discussions, Entergy’s utility supply plan, and recovery of fuel and purchased power costs, as well as delays in cost recovery resulting from these proceedings;

•continuing long-term risks and uncertainties associated with the termination of the System Agreement in 2016, including the potential absence of federal authority to resolve certain issues among the Utility operating companies and their retail regulators;

•regulatory and operating challenges and uncertainties and economic risks associated with the Utility operating companies’ participation in MISO, including the benefits of continued MISO participation, the effect of current or projected MISO market rules and market and system conditions in the MISO markets, the allocation of MISO system transmission upgrade costs, the MISO-wide base rate of return on equity allowed or any MISO-related charges and credits required by the FERC, and the effect of planning decisions that MISO makes with respect to future transmission investments by the Utility operating companies;

•changes in utility regulation, including with respect to retail and wholesale competition, the ability to recover net utility assets and other potential stranded costs, and the application of more stringent return on equity criteria, transmission reliability requirements or market power criteria by the FERC or the U.S. Department of Justice;

•changes in the regulation or regulatory oversight of Entergy’s owned or operated nuclear generating facilities and nuclear materials and fuel, including with respect to the planned shutdown and sale of Palisades, and the effects of new or existing safety or environmental concerns regarding nuclear power plants and fuel;

•resolution of pending or future applications, and related regulatory proceedings and litigation, for license modifications or other authorizations required of nuclear generating facilities and the effect of public and political opposition on these applications, regulatory proceedings, and litigation;

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

•increases in costs and capital expenditures that could result from changing regulatory requirements, emerging operating and industry issues, and the commitment of substantial human and capital resources required for the safe and reliable operation and maintenance of Entergy’s nuclear generating facilities;

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FORWARD-LOOKING INFORMATION (Continued)

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

•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, emissions allowances, and other energy-related commodities, and the effect of those changes on Entergy and its customers;

•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;

•changes in environmental laws and regulations, agency positions or associated litigation, including requirements for reduced emissions of sulfur dioxide, nitrogen oxide, greenhouse gases, mercury, particulate matter and other regulated air emissions, heat and other regulated discharges to water, requirements for waste management and disposal and for the remediation of contaminated sites, wetlands protection and permitting, and changes in costs of compliance with environmental laws and regulations;

•changes in laws and regulations, agency positions, or associated litigation related to protected species and associated critical habitat designations;

•the effects of changes in federal, state, or local laws and regulations, and other governmental actions or policies, including changes in monetary, fiscal, tax, environmental, trade/tariff, domestic purchase requirements, or energy policies;

•the effects of full or partial shutdowns of the federal government or delays in obtaining government or regulatory actions or decisions;

•uncertainty regarding the establishment of interim or permanent sites for spent nuclear fuel and nuclear waste storage and disposal and the level of spent fuel and nuclear waste disposal fees charged by the U.S. government or other providers related to such sites;

•variations in weather and the occurrence of hurricanes and other storms and disasters, including uncertainties associated with efforts to remediate the effects of hurricanes (including from Hurricane Laura, Hurricane Delta, and Hurricane Zeta), 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, as well as any related unplanned outages;

•the risk that an incident at any nuclear generation facility in the U.S. could lead to the assessment of significant retrospective assessments and/or retrospective insurance premiums as a result of Entergy’s participation in a secondary financial protection system, a utility industry mutual insurance company, and industry self-insurance programs;

•effects of climate change, including the potential for increases in extreme weather events and sea levels or coastal land and wetland loss;

•changes in the quality and availability of water supplies and the related regulation of water use and diversion;

•Entergy’s ability to manage its capital projects, including completion of projects timely and within budget and to obtain the anticipated performance or other benefits, and its 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 area and events and circumstances that could influence economic conditions in those areas, including power prices, and the risk that anticipated load growth may not materialize;

•changes to federal income tax laws and regulations, including continued impact of the Tax Cuts and Jobs Act and its intended and unintended consequences on financial results and future cash flows;

•the effects of Entergy’s strategies to reduce tax payments;

•changes in the financial markets and regulatory requirements for the issuance of securities, particularly as they affect access to capital and Entergy’s ability to refinance existing securities, 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;

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FORWARD-LOOKING INFORMATION (Concluded)

•changes in inflation and interest rates;

•the effects of litigation and government investigations or proceedings;

•changes in technology, including (i) Entergy’s ability to implement new or emerging technologies, (ii) the impact of changes relating to new, developing, or alternative sources of generation such as distributed energy and energy storage, renewable energy, energy efficiency, demand side management and other measures that reduce load and government policies incentivizing development of the foregoing, and (iii) competition from other companies offering products and services to Entergy’s customers based on new or emerging technologies or alternative sources of generation;

•Entergy’s ability to effectively formulate and implement plans to reduce its carbon emission rate and aggregate carbon emissions, including its commitment to achieve net-zero carbon emissions by 2050, and the potential impact on its business of attempting to achieve such objectives;

•the effects, including increased security costs, of threatened or actual terrorism, cyber-attacks or data security breaches, natural or man-made electromagnetic pulses that affect transmission or generation infrastructure, accidents, and war or a catastrophic event such as a nuclear accident or a natural gas pipeline explosion;

•the effects of a global event or pandemic, such as the COVID-19 global pandemic, including economic and societal disruptions; volatility in the capital markets (and any related increased cost of capital or any inability to access the capital markets or draw on available bank credit facilities); reduced demand for electricity, particularly from commercial and industrial customers; increased or unrecoverable costs; supply chain, vendor, and contractor disruptions; delays in completion of capital or other construction projects, maintenance, and other operations activities, including prolonged or delayed outages; impacts to Entergy’s workforce availability, health, or safety; increased cybersecurity risks as a result of many employees telecommuting; increased late or uncollectible customer payments; regulatory delays; executive orders affecting, or increased regulation of, Entergy’s business; changes in credit ratings or outlooks as a result of any of the foregoing; or other adverse impacts on Entergy’s ability to execute on its business strategies and initiatives or, more generally, on Entergy’s results of operations, financial condition, and liquidity;

•Entergy’s ability to attract and retain talented management, directors, and employees with specialized skills;

•Entergy’s ability to attract, retain, and manage an appropriately qualified workforce;

•changes in accounting standards and corporate governance;

•declines in the market prices of marketable securities and resulting funding requirements and the effects on benefits costs for Entergy’s defined benefit pension and other postretirement benefit plans;

•future wage and employee benefit costs, including changes in discount rates and returns on benefit plan assets;

•changes in decommissioning trust fund values or earnings or in the timing of, requirements for, or cost to decommission Entergy’s nuclear plant sites and the implementation of decommissioning of such sites following shutdown;

•the decision to cease merchant power generation at all Entergy Wholesale Commodities nuclear power plants by mid-2022, including the implementation of the planned shutdown and sale of Palisades;

•the effectiveness of Entergy’s risk management policies and procedures and the ability and willingness of its counterparties to satisfy their financial and performance commitments;

•the potential for the factors listed herein to lead to the impairment of long-lived assets; and

•Entergy and its subsidiaries’ ability to successfully execute on their business strategies, including their ability to complete strategic transactions that Entergy may undertake.

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DEFINITIONS

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

Abbreviation or Acronym			Term
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.
capacity factor			Actual plant output divided by maximum potential plant output for the period
City Council			Council of the City of New Orleans, Louisiana
COVID-19			The novel coronavirus disease declared a pandemic by the World Health Organization and the Centers for Disease Control and Prevention in March 2020
D.C. Circuit			U.S. Court of Appeals for the District of Columbia Circuit
DOE			United States Department of Energy
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 Louisiana limited liability 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. Effective October 1, 2015, the business of Entergy Gulf States Louisiana was combined with Entergy Louisiana.
Entergy Louisiana			Entergy Louisiana, LLC, a Texas limited liability company formally created as part of the combination of Entergy Gulf States Louisiana and the company formerly known as Entergy Louisiana, LLC (Old Entergy Louisiana) into a single public utility company and the successor to Old Entergy Louisiana for financial reporting purposes.
Entergy Texas			Entergy Texas, Inc., a Texas corporation 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			Entergy’s non-utility business segment primarily comprised of the ownership, operation, and decommissioning of nuclear power plants, the ownership of interests in non-nuclear power plants, and the sale of the electric power produced by its operating power plants to wholesale customers
EPA			United States Environmental Protection Agency
FASB			Financial Accounting Standards Board
FERC			Federal Energy Regulatory Commission
Form 10-K			Annual Report on Form 10-K for the calendar year ended December 31, 2020 filed with the SEC by Entergy Corporation and its Registrant Subsidiaries
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
Independence			Independence Steam Electric Station (coal), owned 16% by Entergy Arkansas, 25% by Entergy Mississippi, and 7% by Entergy Power, LLC

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DEFINITIONS (Continued)

Abbreviation or Acronym			Term
Indian Point 2			Unit 2 of Indian Point Energy Center (nuclear), previously owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in April 2020 and was sold in May 2021
Indian Point 3			Unit 3 of Indian Point Energy Center (nuclear), previously owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in April 2021 and was sold in May 2021
IRS			Internal Revenue Service
ISO			Independent System Operator
kW			Kilowatt, which equals one thousand watts
kWh			Kilowatt-hour(s)
LPSC			Louisiana Public Service Commission
MISO			Midcontinent Independent 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 kilowatts
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 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 to net capital 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
Palisades			Palisades Nuclear Plant (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
Parent & Other			The portions of Entergy not included in the Utility or Entergy Wholesale Commodities segments, primarily consisting of the activities of the parent company, Entergy Corporation
Pilgrim			Pilgrim Nuclear Power Station (nuclear), previously owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in May 2019 and was sold in August 2019
PPA			Purchased power agreement or power purchase agreement
PUCT			Public Utility Commission of Texas
Registrant Subsidiaries			Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, Entergy New Orleans, LLC, Entergy Texas, Inc., and System Energy Resources, Inc.
River Bend			River Bend Station (nuclear), owned by Entergy Louisiana
SEC			Securities and Exchange Commission
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. The agreement terminated effective August 2016.
System Energy			System Energy Resources, Inc.
TWh			Terawatt-hour(s), which equals one billion kilowatt-hours

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DEFINITIONS (Concluded)

Abbreviation or Acronym			Term
Unit Power Sales Agreement			Agreement, dated as of June 10, 1982, as amended and approved by the 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 Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas
Waterford 3			Unit No. 3 (nuclear) of the Waterford Steam Electric Station, owned 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 operation of a small natural gas distribution business.  

•The Entergy Wholesale Commodities business segment includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. See “Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for discussion of the operation and planned shutdown and sale of each of the Entergy Wholesale Commodities nuclear power plants.

See Note 7 to the financial statements herein for financial information regarding Entergy’s business segments.

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic and its effects on Entergy’s business.

Hurricane Laura, Hurricane Delta, and Hurricane Zeta

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Laura, Hurricane Delta, and Hurricane Zeta” in the Form 10-K for a discussion of Hurricane Laura, Hurricane Delta, and Hurricane Zeta, which caused significant damage to portions of the Utility’s service territories in Louisiana, including New Orleans, Texas, and to a lesser extent, in Arkansas and Mississippi. See Note 2 to the financial statements herein for discussion of storm cost filings made in 2021 by Entergy Louisiana, Entergy New Orleans, and Entergy Texas.

Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for February 2021 for Entergy were approximately $720 million, including $145 million for Entergy Arkansas, $285 million for Entergy Louisiana, $65 million for Entergy Mississippi, $35 million for Entergy New Orleans, and $185 million for Entergy Texas. This compares to fuel and purchased power costs for February 2020 for Entergy of $245 million, including $40 million for Entergy Arkansas, $95 million for Entergy Louisiana, $35 million for Entergy Mississippi, $25 million for Entergy New Orleans, and $50 million for Entergy Texas. See Note 2 to the financial statements herein for discussion of storm cost filings made in 2021 by Entergy Louisiana and Entergy Texas. See Note 2 to the financial statements herein and in the Form 10-K for discussion of fuel cost recovery at the Utility operating companies.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Results of Operations

Second Quarter 2021 Compared to Second Quarter 2020

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the second quarter 2021 to the second quarter 2020 showing how much the line item increased or (decreased) in comparison to the prior period:

						Utility						Entergy Wholesale Commodities						Parent & Other (a)						Entergy
						(In Thousands)
2020 Net Income (Loss) Attributable to Entergy Corporation						$344,869						$84,631						($68,967)						$360,533
Operating revenues						460,324						(51,053)						11						409,282
Fuel, fuel-related expenses, and gas purchased for resale						284,683						376						—						285,059
Purchased power						32,515						7,895						—						40,410
Other regulatory charges (credits) - net						(29,891)						—						—						(29,891)
Other operation and maintenance						102,213						(56,992)						(364)						44,857
Asset write-offs, impairments, and related charges						—						335,317						—						335,317
Taxes other than income taxes						5,654						(8,346)						(43)						(2,735)
Depreciation and amortization						28,904						(11,040)						(88)						17,776
Other income (deductions)						(45,535)						(152,885)						4,205						(194,215)
Interest expense						10,085						(2,809)						1,444						8,720
Other expenses						1,942						(12,350)						—						(10,408)
Income taxes						(2,350)						(96,163)						(9,018)						(107,531)
2021 Net Income (Loss) Attributable to Entergy Corporation						$325,903						($275,195)						($56,682)						($5,974)

(a)Parent & Other includes eliminations, which are primarily intersegment activity.

Second quarter 2021 results of operations include a charge of $340 million ($268 million net-of-tax) as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements herein for further discussion of the sale of the Indian Point Energy Center.

Second quarter 2020 results of operations include gains of $225 million (pre-tax) on Entergy Wholesale Commodities’ nuclear decommissioning trust fund investments reflecting the equity market rebound from the March 2020 decline associated with the COVID-19 pandemic. See Notes 8 and 9 to the financial statements herein for a discussion of decommissioning trust fund investments.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Operating Revenues

Utility

Following is an analysis of the change in operating revenues comparing the second quarter 2021 to the second quarter 2020:

			Amount
			(In Millions)
2020 operating revenues			$2,213
Fuel, rider, and other revenues that do not significantly affect net income			354
Retail electric price			96
Volume/weather			10
2021 operating revenues			$2,673

The Utility operating companies’ results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The retail electric price variance is primarily due to:

•an increase in Entergy Arkansas’s formula rate plan rates effective with the first billing cycle of May 2021;

•increases in Entergy Louisiana’s overall formula rate plan revenues, including an increase in the transmission recovery mechanism effective September 2020, and an interim increase effective December 2020 due to the inclusion of the first-year revenue requirement for the Washington Parish Energy Center;

•an increase in Entergy Mississippi’s formula rate plan rates effective, in part, with the first billing cycle of April 2021;

•an interim increase in Entergy New Orleans’s formula rate plan revenues resulting from the recovery of New Orleans Power Station costs, effective November 2020; and

•the implementation of the generation cost recovery rider, which includes the first-year revenue requirement for the Montgomery County Power Station, effective January 2021, an increase in the transmission cost recovery factor rider effective March 2021, and an increase in the distribution cost recovery factor rider effective March 2021, each at Entergy Texas.

See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the regulatory proceedings discussed above.

The volume/weather variance is primarily due to an increase of 777 GWh, or 3%, in billed electricity usage primarily due to an increase in commercial usage resulting from reduced impacts from the COVID-19 pandemic on businesses as compared to prior year and an increase in industrial usage primarily due to an increase in demand from expansion projects, primarily in the transportation, metals, and chemicals industries, and an increase in demand from cogeneration customers. The increase was partially offset by a decrease in usage from residential customers primarily due to the impact that the COVID-19 pandemic had on prior year usage. See “The COVID-19 Pandemic” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for discussion of the COVID-19 pandemic.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Billed electric energy sales for Utility for the three months ended June 30, 2021 and 2020 are as follows:

			2021						2020						% Change
			(GWh)
Residential			7,361						7,759						(5)
Commercial			6,370						6,071						5
Industrial			12,690						11,846						7
Governmental			602						570						6
Total retail			27,023						26,246						3
Sales for resale			4,716						3,111						52
Total			31,739						29,357						8

See Note 13 to the financial statements herein for additional discussion of operating revenues.

Entergy Wholesale Commodities

Operating revenues for Entergy Wholesale Commodities decreased from $200 million for the second quarter 2020 to $149 million for the second quarter 2021 primarily due to the shutdown of Indian Point 3 in April 2021 and the shutdown of Indian Point 2 in April 2020.

Following are key performance measures for Entergy Wholesale Commodities for the second quarters 2021 and 2020:

			2021						2020
Owned capacity (MW) (a)			1,205						2,246
GWh billed			2,687						4,958
Entergy Wholesale Commodities Nuclear Fleet
Capacity factor			94%						96%
GWh billed			2,356						4,580
Average energy price ($/MWh)			$48.75						$35.48
Average capacity price ($/kW-month)			$0.32						$2.33

The Entergy Wholesale Commodities nuclear power plants had no refueling outage days in the second quarters of 2021 and 2020.

(a)The reduction in owned capacity is due to the shutdown of the 1,041 MW Indian Point 3 plant in April 2021.

Other Income Statement Items

Utility

Other operation and maintenance expenses increased from $589 million for the second quarter 2020 to $691 million for the second quarter 2021 primarily due to:

•an increase of $16 million in non-nuclear generation expenses primarily due to a higher scope of work performed during plant outages in 2021 as compared to 2020 and higher expenses associated with plants placed in service, including the New Orleans Power Station, which began commercial operation in May

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Management's Financial Discussion and Analysis

2020; the Washington Parish Energy Center, purchased in November 2020; and the Montgomery County Power Station, which began commercial operation in January 2021;

•an increase of $15 million in nuclear generation expenses primarily due to higher nuclear labor costs and a higher scope of work performed in 2021 as compared to 2020;

•an increase of $14 million in compensation and benefits costs primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs;

•an increase of $14 million in distribution operations expenses primarily due to higher distribution reliability costs and higher vegetation maintenance costs;

•the effects of recording in second quarter 2020 final judgments to resolve claims in the Waterford 3 damages case against the DOE related to spent nuclear fuel storage costs. The damages awarded included the reimbursement of approximately $8 million of spent nuclear fuel storage costs previously recorded as other operation and maintenance expense. See Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation;

•an increase of $7 million in information technology costs primarily due to higher contract costs and higher costs associated with system maintenance;

•an increase of $6 million primarily due to contract costs in 2021 related to customer solutions and sustainability initiatives; and

•several individually insignificant items.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Montgomery County Power Station.

Other regulatory charges (credits) - net includes:

•regulatory credits of $11 million, recorded in the second quarter 2020 at Entergy Arkansas, to reflect the amortization of the 2018 historical year netting adjustment reflected in the 2019 formula rate plan filing. See Note 2 to the financial statements in the Form 10-K for discussion of the 2019 formula rate plan filing; and

•regulatory credits of $20 million, recorded in the second quarter 2021 at Entergy Mississippi, to reflect the effects of the joint stipulation reached in the 2021 formula rate plan filing proceeding. See Note 2 to the financial statements herein for discussion of the 2021 formula rate plan filing.

Other income decreased primarily due to changes in decommissioning trust fund activity and a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2020, including the Montgomery County Power Station project.

Interest expense increased primarily due to:

•the issuances by Entergy Louisiana of $1.1 billion of 0.62% Series mortgage bonds, $300 million of 2.90% Series mortgage bonds, and $300 million of 1.60% Series mortgage bonds, each in November 2020;

•the issuances by Entergy Louisiana of $500 million of 2.35% Series mortgage bonds and $500 million of 3.10% Series mortgage bonds, each in March 2021;

•the issuance by Entergy Mississippi of $370 million of 3.50% Series mortgage bonds in March 2021; and

•a decrease in the allowance for borrowed funds used during construction due to higher construction work in progress in 2020, including the Montgomery County Power Station project.

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Management's Financial Discussion and Analysis

The increase was partially offset by:

•the repayments by Entergy Louisiana of $200 million of 5.25% Series mortgage bonds and $100 million of 4.70% Series mortgage bonds, each in December 2020; and

•the repayment by Entergy Louisiana of $200 million of 4.8% Series mortgage bonds in May 2021.

Entergy Wholesale Commodities

Other operation and maintenance expenses decreased from $140 million for the second quarter 2020 to $83 million for the second quarter 2021 primarily due to:

•a decrease of $35 million primarily resulting from the absence of expenses from Indian Point 2, after it was shut down in April 2020, and Indian Point 3, after it was shut down in April 2021; and

•a decrease of $22 million in severance and retention expenses. Severance and retention expenses were incurred in 2021 and 2020 due to management’s strategy to exit the Entergy Wholesale Commodities merchant power business.

See “Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to shut down and sell all of the plants in Entergy Wholesale Commodities’ merchant nuclear fleet. See Note 7 to the financial statements herein for further discussion of severance and retention expenses.

Asset write-offs, impairments, and related charges for the second quarter 2021 include a charge of $340 million ($268 million net-of-tax) as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements herein for further discussion of the sale of the Indian Point Energy Center. See “Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to shut down and sell all of the plants in the Entergy Wholesale Commodities merchant nuclear fleet.

Depreciation and amortization expenses decreased primarily due to the absence of depreciation expense from Indian Point 3, after it was shut down in April 2021, and Indian Point 2, after it was shut down in April 2020.

Other income decreased primarily due to lower gains on decommissioning trust fund investments, including the absence of earnings from nuclear decommissioning trust funds that were transferred in the sale of the Indian Point Energy Center in May 2021. See Notes 8 and 9 to the financial statements herein for a discussion of decommissioning trust fund investments. See Note 14 to the financial statements herein for further discussion of the sale of the Indian Point Energy Center.

Other expenses decreased primarily due to the absence of decommissioning expense from Indian Point 2 and Indian Point 3, after the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements herein for further discussion of the sale of the Indian Point Energy Center.

Income Taxes

The effective income tax rate was 93% for the second quarter 2021. The difference in the effective income tax rate for the second quarter 2021 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, a reduction of a valuation allowance, certain book and tax differences related to utility plant items, and book and tax differences related to the allowance for equity funds used during construction, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 10 to the financial statements herein for discussion of the valuation allowance reduction.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

The effective income tax rate was 19.6% for the second quarter 2020. The difference in the effective income tax rate for the second quarter 2020 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes and certain book and tax differences related to utility plant items, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the six months ended June 30, 2021 to the six months ended June 30, 2020 showing how much the line items increased or (decreased) in comparison to the prior period:

						Utility						Entergy Wholesale Commodities						Parent & Other (a)						Entergy
						(In Thousands)
2020 Net Income (Loss) Attributable to Entergy Corporation						$664,685						($26,344)						($159,094)						$479,247
Operating revenues						962,310						(135,384)						14						826,940
Fuel, fuel-related expenses, and gas purchased for resale						387,363						1,470						(10)						388,823
Purchased power						188,483						15,037						10						203,530
Other regulatory charges (credits)						10,066						—						—						10,066
Other operation and maintenance						138,801						(89,042)						(200)						49,559
Asset write-offs, impairments, and related charges						—						333,495						—						333,495
Taxes other than income taxes						5,399						(21,988)						262						(16,327)
Depreciation and amortization						65,956						(33,187)						(183)						32,586
Other income (deductions)						(15,488)						65,285						10,463						60,260
Interest expense						23,933						(3,914)						(1,570)						18,449
Other expenses						(1,297)						(10,633)						—						(11,930)
Income taxes						110,333						(50,062)						(30,666)						29,605
2021 Net Income (Loss) Attributable to Entergy Corporation						$682,470						($237,619)						($116,260)						$328,591

(a)Parent & Other includes eliminations, which are primarily intersegment activity.

Results of operations for the six months ended June 30, 2021 include a charge of $340 million ($268 million net-of-tax) as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements herein for further discussion of the sale of the Indian Point Energy Center.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Operating Revenues

Utility

Following is an analysis of the change in operating revenues comparing the six months ended June 30, 2021 to the six months ended June 30, 2020:

			Amount
			(In Millions)
2020 operating revenues			$4,308
Fuel, rider, and other revenues that do not significantly affect net income			682
Retail electric price			187
Volume/weather			107
Return of unprotected excess accumulated deferred income taxes to customers			(14)
2021 operating revenues			$5,270

The Utility operating companies’ results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The retail electric price variance is primarily due to:

•an increase in Entergy Arkansas’s formula rate plan rates effective with the first billing cycle of May 2021;

•increases in Entergy Louisiana’s overall formula rate plan revenues, including an interim increase effective April 2020 due to the inclusion of the first-year revenue requirement for the Lake Charles Power Station, an increase in the transmission recovery mechanism effective September 2020, and an interim increase effective December 2020 due to the inclusion of the first-year revenue requirement for the Washington Parish Energy Center;

•increases in Entergy Mississippi’s formula rate plan rates effective, in part, with the first billing cycles of April 2020 and April 2021 and the implementation of a vegetation management rider effective with the April 2020 billing cycle;

•an interim increase in Entergy New Orleans’s formula rate plan revenues resulting from the recovery of New Orleans Power Station costs, effective November 2020; and

•the implementation of the generation cost recovery rider, which includes the first-year revenue requirement for the Montgomery County Power Station, effective January 2021, an increase in the transmission cost recovery factor rider effective March 2021, and an increase in the distribution cost recovery factor rider effective March 2021, each at Entergy Texas.

See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the regulatory proceedings discussed above.

The volume/weather variance is primarily due to an increase of 1,767 GWh, or 3%, in billed electricity usage, including the effect of more favorable weather on residential sales, an increase in industrial usage, and an increase in usage during the unbilled sales period. The increase in industrial usage is primarily due to an increase in demand from expansion projects, primarily in the transportation, metals, and chemicals industries, partially offset by decreased demand from existing customers in the chemicals and petroleum refining industries as a result of temporary plant shutdowns and operational issues.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

The return of unprotected excess accumulated deferred income taxes to customers resulted from activity at the Utility operating companies in response to the enactment of the Tax Cuts and Jobs Act. The return of unprotected excess accumulated deferred income taxes began in the second quarter 2018. In the six months ended June 30, 2021, $54 million was returned to customers through reductions in operating revenues as compared to $40 million in the six months ended June 30, 2020. There is no effect on net income as the reductions in operating revenues were offset by reductions in income tax expense. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.     

Billed electric energy sales for Utility for the six months ended June 30, 2021 and 2020 are as follows:

			2021						2020						% Change
			(GWh)
Residential			16,961						15,885						7
Commercial			12,504						12,315						2
Industrial			24,148						23,662						2
Governmental			1,181						1,165						1
Total retail			54,794						53,027						3
Sales for resale			9,016						6,228						45
Total			63,810						59,255						8

See Note 13 to the financial statements herein for additional discussion of operating revenues.

Entergy Wholesale Commodities

Operating revenues for Entergy Wholesale Commodities decreased from $532 million for the six months ended June 30, 2020 to $397 million for the six months ended June 30, 2021 primarily due to the shutdown of Indian Point 2 in April 2020 and the shutdown of Indian Point 3 in April 2021.

Following are key performance measures for Entergy Wholesale Commodities for the six months ended June 30, 2021 and 2020:

			2021						2020
Owned capacity (MW) (a)			1,205						2,246
GWh billed			7,099						11,714
Entergy Wholesale Commodities Nuclear Fleet
Capacity factor			97%						98%
GWh billed			6,344						10,839
Average energy price ($/MWh)			$50.70						$42.37
Average capacity price ($/kW-month)			$0.26						$1.58

The Entergy Wholesale Commodities nuclear power plants had no refueling outage days in the six months ended June 30, 2021 and 2020.

(a)The reduction in owned capacity is due to the shutdown of the 1,041 MW Indian Point 3 plant in April 2021.

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Management's Financial Discussion and Analysis

Other Income Statement Items

Utility

Other operation and maintenance expenses increased from $1,155 million for the six months ended June 30, 2020 to $1,294 million for the six months ended June 30, 2021 primarily due to:

•an increase of $24 million in non-nuclear generation expenses primarily due to a higher scope of work performed during plant outages in 2021 as compared to 2020 and higher expenses associated with plants placed in service, including the Lake Charles Power Station, which began commercial operation in March 2020; the New Orleans Power Station, which began commercial operation in May 2020; the Washington Parish Energy Center, purchased in November 2020; and the Montgomery County Power Station, which began commercial operation in January 2021;

•an increase of $20 million in nuclear generation expenses primarily due to higher nuclear labor costs and a higher scope of work performed in 2021 as compared to 2020;

•an increase of $18 million in compensation and benefits costs primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs;

•an increase of $17 million in distribution operations expenses primarily due to higher distribution reliability costs and higher vegetation maintenance costs;

•lower nuclear insurance refunds of $13 million;

•the effects of recording in second quarter 2020 final judgments to resolve claims in the Waterford 3 damages case against the DOE related to spent nuclear fuel storage costs. The damages awarded included the reimbursement of approximately $8 million of spent nuclear fuel storage costs previously recorded as other operation and maintenance expense. See Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation;

•an increase of $8 million as a result of the amount of transmission costs allocated by MISO. See Note 2 to the financial statements in the Form 10-K for further information on the recovery of these costs;

•an increase of $7 million primarily due to contract costs in 2021 related to customer solutions and sustainability initiatives; and

•an increase of $6 million in information technology costs due to higher contract costs and higher costs associated with system maintenance.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Lake Charles Power Station and the Montgomery County Power Station.

Other regulatory charges (credits) - net includes:

•regulatory credits of $22 million, recorded in 2020 at Entergy Arkansas, to reflect the amortization of the 2018 historical year netting adjustment reflected in the 2019 formula rate plan filing. See Note 2 to the financial statements in the Form 10-K for discussion of the 2019 formula rate plan filing;

•the reversal in 2021 of the remaining $39 million regulatory liability for Entergy Arkansas’s 2019 historical year netting adjustment as part of its 2020 formula rate plan proceeding. See Note 2 to the financial statements herein and in the Form 10-K for discussion of Entergy Arkansas’s 2020 formula rate plan filing;

•$29 million recorded in the first quarter 2020, at Entergy Louisiana, due to a settlement with the IRS related to the uncertain tax position regarding the Hurricane Isaac Louisiana Act 55 financing because the savings will be shared with customers. See Note 3 to the financial statements in the Form 10-K for further discussion of the settlement and savings obligation; and

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Management's Financial Discussion and Analysis

•regulatory credits of $20 million, recorded in the second quarter 2021 at Entergy Mississippi, to reflect the effects of the joint stipulation reached in the 2021 formula rate plan filing proceeding. See Note 2 to the financial statements herein for discussion of the 2021 formula rate plan filing.

Other income decreased primarily due to a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2020, including the Lake Charles Power Station project and the Montgomery County Power Station project, partially offset by changes in decommissioning trust fund activity.

Interest expense increased primarily due to:

•the issuance by Entergy Louisiana of $350 million of 2.90% Series mortgage bonds in March 2020;

•the issuances by Entergy Louisiana of $1.1 billion of 0.62% Series mortgage bonds, $300 million of 2.90% Series mortgage bonds, and $300 million of 1.60% Series mortgage bonds, each in November 2020;

•the issuances by Entergy Louisiana of $500 million of 2.35% Series mortgage bonds and $500 million of 3.10% Series mortgage bonds, each in March 2021;

•the issuance by Entergy Mississippi of $370 million of 3.50% Series mortgage bonds in March 2021; and

•a decrease in the allowance for borrowed funds used during construction due to higher construction work in progress in 2020, including the Lake Charles Power Station project and the Montgomery County Power Station project.

The increase was partially offset by:

•the repayments by Entergy Louisiana of $200 million of 5.25% Series mortgage bonds and $100 million of 4.70% Series mortgage bonds, each in December 2020; and

•the repayment by Entergy Louisiana of $200 million of 4.8% Series mortgage bonds in May 2021.

Entergy Wholesale Commodities

Other operation and maintenance expenses decreased from $271 million for the six months ended June 30, 2020 to $182 million for the six months ended June 30, 2021 primarily due to:

•a decrease of $63 million resulting from the absence of expenses from Indian Point 2, after it was shut down in April 2020, and Indian Point 3, after it was shut down in April 2021; and

•a decrease of $28 million in severance and retention expenses. Severance and retention expenses were incurred in 2021 and 2020 due to management’s strategy to exit the Entergy Wholesale Commodities merchant power business.

See “Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. See Note 7 to the financial statements herein for further discussion of severance and retention expenses.

Asset write-offs, impairments, and related charges for the six months ended June 30, 2021 include a charge of $340 million ($268 million net-of-tax) as a result of the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements herein for further discussion of the sale of the Indian Point Energy Center. See “Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to shut down and sell all of the remaining plants in the Entergy Wholesale Commodities merchant nuclear fleet.

Taxes other than income taxes decreased primarily due to lower payroll taxes and lower ad valorem taxes.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Depreciation and amortization expenses decreased primarily due to:

•the absence of depreciation expense from Indian Point 2, after it was shut down in April 2020, and from Indian Point 3, after it was shut down in April 2021; and

•the effect of recording in 2021 a final judgment to resolve claims in the Palisades damages case against the DOE related to spent nuclear fuel storage costs. The damages awarded included $9 million of spent nuclear fuel storage costs previously recorded as depreciation expense. See Note 1 to the financial statements herein for discussion of the spent nuclear fuel litigation.

Other income increased primarily due to higher gains on decommissioning trust fund investments, partially offset by the absence of earnings from nuclear decommissioning trust funds that were transferred in the sale of the Indian Point Energy Center in May 2021. See Notes 8 and 9 to the financial statements herein for a discussion of decommissioning trust fund investments. See Note 14 to the financial statements herein for further discussion of the sale of the Indian Point Energy Center.

Other expenses decreased primarily due to the absence of decommissioning expense from Indian Point 2 and Indian Point 3, after the sale of the Indian Point Energy Center in May 2021. See Note 14 to the financial statements herein for further discussion of the sale of the Indian Point Energy Center.

Income Taxes

The effective income tax rate was 12.3% for the six months ended June 30, 2021. The difference in the effective income tax rate for the six months ended June 30, 2021 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, a reduction of a valuation allowance, certain book and tax differences related to utility plant items, and book and tax differences related to the allowance for equity funds used during construction, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 10 to the financial statements herein for discussion of the valuation allowance reduction.

The effective income tax rate was 3.5% for the six months ended June 30, 2020. The difference in the effective income tax rate for the six months ended June 30, 2020 versus the federal statutory rate of 21% was primarily due to the settlement with the IRS on the treatment of funds received in conjunction with the Act 55 financing of Hurricane Isaac storm costs, permanent differences related to income tax deductions for stock-based compensation, amortization of excess accumulated deferred income taxes, and certain book and tax differences related to utility plant items, partially offset by state income taxes. See Note 3 to the financial statements in the Form 10-K for discussion of the IRS settlement and the income tax deductions for stock-based compensation. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

Entergy Wholesale Commodities Exit from the Merchant Power Business

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” in the Form 10-K for a discussion of management’s strategy to shut down and sell all remaining plants in the Entergy Wholesale Commodities merchant nuclear fleet.  Following are updates to that discussion.

Shutdown and Sale of Indian Point 2 and Indian Point 3

As discussed in the Form 10-K, in April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3 to a Holtec subsidiary for decommissioning the plants.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

In November 2019, Entergy and Holtec submitted a license transfer application to the NRC. The NRC issued an order approving the application in November 2020, subject to the NRC’s authority to condition, revise, or rescind the approval order based on the resolution of four pending hearing requests. In January 2021 the NRC issued an order denying all four hearing requests challenging the license transfer application. In January 2021, New York State filed a petition for review with the D.C. Circuit asking the court to vacate the NRC’s January 2021 order denying the State’s hearing request, as well as the NRC’s November 2020 order approving the license transfers. In January 2021 the D.C. Circuit issued a scheduling order, setting deadlines for initial procedural filings in March 2021. In March 2021 additional parties also filed petitions for review with the D.C. Circuit seeking review of the same NRC orders. In March 2021 the court consolidated all of the appeals into the same proceeding. Pursuant to an April 2021 settlement among Entergy, Holtec, New York State, and several other parties, discussed below, all petitioners to the D.C. Circuit proceeding withdrew their pending appeals, and the court terminated the consolidated proceeding in June 2021.

In November 2019, Entergy and Holtec also submitted a petition to the New York State Public Service Commission (NYPSC) seeking an order from the NYPSC disclaiming jurisdiction or abstaining from review of the transaction or, alternatively, approving the transaction. Closing was also conditioned on obtaining from the New York State Department of Environmental Conservation an agreement related to Holtec’s decommissioning plan as being consistent with applicable standards. In April 2021, Entergy and Holtec filed a joint settlement proposal with the NYPSC that resolved all issues among all parties, including financial assurance, site restoration, financial reporting, continued funding for state and local emergency management and response activities, a memorandum of understanding with local taxing jurisdictions, and the dismissal of the federal appeals described in the preceding paragraph. In May 2021 the NYPSC approved the joint settlement proposal and the transaction.

Indian Point 2 permanently ceased operations on April 30, 2020 and Indian Point 3 permanently ceased operations on April 30, 2021. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. See Note 14 to the financial statements for discussion of the closing of the Indian Point transaction.

Planned Shutdown and Sale of Palisades

As discussed in the Form 10-K, in July 2018, Entergy entered into a purchase and sale agreement to sell 100% of the equity interests in the subsidiary that owns Palisades and the Big Rock Point Site, for $1,000 (subject to adjustment for net liabilities and other amounts) to a Holtec subsidiary. The sale will include the transfer of the nuclear decommissioning trust and obligation for spent fuel management and plant decommissioning.

In December 2020, Entergy and Holtec submitted a license transfer application to the NRC requesting approval to transfer the Palisades and Big Rock Point licenses from Entergy to Holtec. The NRC has indicated that it expects to complete its review of the application by January 2022. In February 2021 several parties filed with the NRC petitions to intervene and requests for hearing challenging the license transfer application. In March 2021, Entergy and Holtec filed answers opposing the petitions to intervene and hearing requests, and the petitioners filed replies. In March 2021 an additional party also filed a petition to intervene and request for hearing. Entergy and Holtec filed an answer to the March 2021 petition in April 2021.

Subject to the conditions discussed in the Form 10-K, the transaction is expected to close by the end of 2022. As of June 30, 2021, Entergy’s adjusted net investment in Palisades was $5 million. The primary variables in the ultimate loss or gain that Entergy will incur on the transaction are the values of the nuclear decommissioning trust and the asset retirement obligations at closing, the financial results from plant operations until the closing, and the level of any unrealized deferred tax balances at closing.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Costs Associated with Entergy Wholesale Commodities Strategic Transactions

Entergy expects to incur employee retention and severance expenses associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business of approximately $10 million in 2021, of which $7 million has been incurred as of June 30, 2021, and a total of approximately $5 million in 2022. In addition, Entergy Wholesale Commodities incurred impairment charges primarily related to expenditures for capital assets of $2 million for the three months ended June 30, 2021 and $5 million for the six months ended June 30, 2021. These costs were charged to expense as incurred as a result of the impaired value of certain of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities merchant power business.

Liquidity and Capital Resources

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy’s capital structure, capital expenditure plans and other uses of capital, and sources of capital.  Following are updates to that discussion.

Capital Structure and Resources

Entergy’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio for Entergy as of June 30, 2021 is primarily due to the net issuance of debt in 2021.

			June 30, 2021						December 31, 2020
Debt to capital			69.5		%				68.3		%
Effect of excluding securitization bonds			(0.1		%)				(0.2		%)
Debt to capital, excluding securitization bonds (a)			69.4		%				68.1		%
Effect of subtracting cash			(0.5		%)				(1.7		%)
Net debt to net capital, excluding securitization bonds (a)			68.9		%				66.4		%

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

As of June 30, 2021, 22.3% of the debt outstanding is at the parent company, Entergy Corporation, 77.2% is at the

Utility, and 0.5% is at Entergy Wholesale Commodities. Net debt consists of debt less cash and cash equivalents.  Debt consists of notes payable and commercial paper, finance 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 debt to capital 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 because the securitization bonds are non-recourse to Entergy, as more fully described in Note 5 to the financial statements in the Form 10-K.  Entergy also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy’s financial condition because net debt indicates Entergy’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

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Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment 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 six months ended June 30, 2021 was 1.61% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2021:

Capacity						Borrowings						Letters of Credit						Capacity Available
(In Millions)
$3,500						$150						$6						$3,344

A covenant in Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, 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. One such difference is that it excludes the effects, among other things, of certain impairments related to the Entergy Wholesale Commodities nuclear generation assets.  Entergy is currently in compliance with the covenant and expects to remain in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy or one of the Registrant Subsidiaries (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility’s maturity date may occur.  See Note 4 to the financial statements herein for additional discussion of the Entergy Corporation credit facility and discussion of the Registrant Subsidiaries’ credit facilities.

Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion. As of June 30, 2021, Entergy Corporation had approximately $866 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2021 was 0.32%.

Certain of the Utility operating companies have a total of $72 million in storm reserve escrow accounts at June 30, 2021.

Equity Distribution Program

In January 2021, Entergy entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy common stock, Entergy may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $1 billion. See Note 3 to the financial statement herein for discussion of the forward sales agreements and common stock issuances and sales under the equity distribution program.

Capital Expenditure Plans and Other Uses of Capital

See the table and discussion in the Form 10-K under “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources - Capital Expenditure Plans and Other Uses of Capital,” that sets forth the amounts of planned construction and other capital investments by operating segment for 2021 through 2023. Following are updates to that discussion.

Searcy Solar Facility

As discussed in the Form 10-K, in April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity

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partnership. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. A decision on the tax equity partnership is requested by September 2021. Entergy Arkansas will purchase the facility upon mechanical completion and after the other purchase contingencies have been met. Closing is expected to occur by the end of 2021.

Walnut Bend Solar Facility

In October 2020, Entergy Arkansas filed a petition with the APSC seeking a finding that the purchase of the 100 MW Walnut Bend Solar Facility is in the public interest. Entergy Arkansas primarily requested cost recovery through the formula rate plan rider. A procedural schedule was established with a paper hearing held in April 2021. In July 2021 the APSC granted Entergy Arkansas’s petition and approved the acquisition of the resource and cost recovery through the formula rate plan rider. In addition, the APSC directed Entergy Arkansas to file a report within 180 days detailing its efforts to obtain a tax equity partnership. Closing is expected to occur in 2022.

Liberty County Solar Facility

In September 2020, Entergy Texas filed an application seeking PUCT approval to amend Entergy Texas’s certificate of convenience and necessity to acquire the 100 MW Liberty County Solar Facility and a determination that Entergy Texas’s acquisition of the facility through a tax equity partnership is in the public interest. In its preliminary order, the PUCT determined that, in considering Entergy Texas’s application, it would not specifically address whether Entergy Texas’s use of a tax equity partnership is in the public interest. In March 2021 intervenors and PUCT staff filed testimony, and Entergy Texas filed rebuttal testimony in April 2021. A hearing on the merits was held in April 2021. Post-hearing and reply briefing was completed in May 2021. In July 2021 the presiding administrative law judges issued a proposal for decision recommending that the PUCT deny the certification requested in the application. This proposal for decision is subject to change based on exceptions filed by the parties. Once it is final, it will be presented to the PUCT, which may adopt or modify it. A decision by the PUCT is expected in September 2021. Closing, subject to receipt of required regulatory approvals and other conditions, is expected to occur in 2023.

Dividends

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 earnings per share from the Utility operating segment and the Parent and Other portion of the business, financial strength, and future investment opportunities.  At its July 2021 meeting, the Board declared a dividend of $0.95 per share, which is the same quarterly dividend per share that Entergy has paid since the third quarter 2020.

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Cash Flow Activity

As shown in Entergy’s Consolidated Statements of Cash Flows, cash flows for the six months ended June 30, 2021 and 2020 were as follows:

			2021						2020
			(In Millions)
Cash and cash equivalents at beginning of period			$1,759						$426
Cash flow provided by (used in):
Operating activities			747						1,448
Investing activities			(2,826)						(2,198)
Financing activities			1,007						1,259
Net increase (decrease) in cash and cash equivalents			(1,072)						509
Cash and cash equivalents at end of period			$687						$935

Operating Activities

Net cash flow provided by operating activities decreased $701 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to the following activity:

•increased fuel costs as a result of Winter Storm Uri. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of fuel and purchased power cost recovery;

•an increase of approximately $160 million in storm spending, primarily due to Hurricane Laura, Hurricane Delta, and Hurricane Zeta restoration efforts. See “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” above for discussion of storm restoration efforts;

•an increase of $108 million in pension contributions in 2021 as compared to the same period in 2020. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding;

•an increase of $105 million in severance and retention payments in 2021 as compared to prior period. See Note 7 to the financial statements herein for a discussion of the severance and retention payments related to Entergy Wholesale Commodities. See “Entergy Wholesale Commodities Exit from the Merchant Power Business” above for a discussion of management’s strategy to exit the Entergy Wholesale Commodities merchant power business;

•a decrease of $45 million in proceeds received from the DOE resulting from litigation regarding spent nuclear fuel storage costs that were previously expensed. See Note 1 to the financial statements herein and Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation;

•income tax payments of $27 million in 2021 compared to income tax refunds of $10 million in 2020. Entergy had net income tax payments in 2021 as a result of amended Mississippi state tax returns filed and other state income taxes paid, offset by federal income tax refunds received associated with the completion of the 2014-2015 IRS audit. Entergy had income tax refunds in 2020 as a result of an overpayment on a prior year state income tax return; and

•a decrease of $18 million of nuclear insurance refunds.

The decrease was partially offset by the timing of collections of receivables from customers and the effect of more favorable weather on billed Utility sales in 2021.

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Investing Activities

Net cash flow used in investing activities increased $628 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to:

•an increase of $777 million in distribution construction expenditures primarily due to storm spending in 2021 and increased spending on the reliability and infrastructure of the distribution system, partially offset by lower spending in 2021 on advanced metering infrastructure. See “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” above for discussion of storm restoration efforts;

•an increase of $231 million in transmission construction expenditures primarily due to storm spending in 2021, partially offset by a lower scope of work on non-storm projects performed in 2021 as compared to 2020. See “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” above for discussion of storm restoration efforts; and

•a decrease of $52 million in proceeds received from the DOE resulting from litigation regarding spent nuclear fuel storage costs that were previously capitalized. See Note 1 to the financial statements herein and Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation.

The increase was partially offset by:

•a decrease of $195 million in non-nuclear generation construction expenditures primarily due to higher spending in 2020 on the Montgomery County Power Station, Lake Charles Power Station, New Orleans Power Station, and New Orleans Solar Station projects;

•a decrease of $93 million in decommissioning trust fund investment activity;

•a decrease of $90 million in nuclear construction expenditures primarily due to decreased spending on various nuclear projects in 2021;

•a decrease of $46 million in information technology expenditures primarily due to decreased spending on various technology projects in 2021; and

•a decrease of $40 million in nuclear fuel purchases due to variations from year to year in the timing and pricing of fuel reload requirements, materials and services deliveries, and the timing of cash payments during the nuclear fuel cycle.

Financing Activities

Net cash flow provided by financing activities decreased $252 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to:

•an increase of $761 million in net repayments of commercial paper in 2021 compared to 2020; and

•a decrease of $38 million in treasury stock issuances in 2021 due to a larger amount of previously repurchased Entergy Corporation common stock issued in 2020 to satisfy stock option exercises.

The decrease was partially offset by:

•long-term debt activity providing approximately $2,108 million of cash in 2021 compared to providing approximately $1,608 million of cash in 2020; and

•net sales proceeds of $27 million from the issuance of common stock in 2021 under the at the market equity distribution program. See Note 3 to the financial statements herein for discussion of the equity distribution program.

For details of Entergy’s commercial paper program and long-term debt, see Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K.

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Rate, Cost-recovery, and Other Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Rate, Cost-recovery, and Other Regulation” in the Form 10-K for discussions of rate regulation, federal regulation, and related regulatory proceedings.

State and Local Rate Regulation and Fuel-Cost Recovery

See Note 2 to the financial statements herein for updates to the discussion in the Form 10-K regarding these proceedings.

Federal Regulation

See Note 2 to the financial statements herein for updates to the discussion in the Form 10-K regarding federal regulatory proceedings.

Market and Credit Risk Sensitive Instruments

Commodity Price Risk

Power Generation

As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  See “Entergy Wholesale Commodities Exit from the Merchant Power Business” above and in the Form 10-K for a discussion of management’s strategy to shut down and sell all remaining plants in the Entergy Wholesale Commodities merchant nuclear fleet.  As of June 30, 2021, Palisades is the only remaining plant in the Entergy Wholesale Commodities merchant nuclear fleet. Almost all of the Palisades output is sold under a power purchase agreement that is scheduled to expire in 2022. Following is a summary of Entergy Wholesale Commodities’ current forward capacity and generation contracts as well as total revenue projections based on market prices as of June 30, 2021 (2021 represents the remainder of the year):

Entergy Wholesale Commodities Nuclear Portfolio

						2021						2022
Energy
Percent of planned generation under contract (a):
Unit-contingent (b)						98%						99%
Planned generation (TWh) (c) (d)						3.4						2.8
Average revenue per MWh on contracted volumes:
Expected based on market prices as of June 30, 2021						$62.1						$47.1
Capacity
Percent of capacity sold forward (e):
Bundled capacity and energy contracts (f)						98%						98%
Planned net MW in operation (average) (d)						803						338
Total Energy and Capacity Revenues (g)
Expected sold and market total revenue per MWh						$61.5						$46.9
Sensitivity: -/+ $10 per MWh market price change						$61.4-$61.7						$46.7-$47.0

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(a)Percent of planned generation output sold under unit-contingent contracts.

(b)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. Certain unit-contingent sales include a guarantee of availability. Availability guarantees provide 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.

(c)Amount of output expected to be generated by Entergy Wholesale Commodities nuclear resources considering plant operating characteristics.

(d)Assumes the planned shutdown of Palisades on May 31, 2022. For a discussion regarding the planned shutdown of the Palisades plant, see “Entergy Wholesale Commodities Exit from the Merchant Power Business” above.

(e)Percent of planned qualified capacity sold to mitigate price uncertainty under physical or financial transactions.

(f)A contract for the sale of installed capacity and related energy, priced per megawatt-hour sold.

(g)Excludes non-cash revenue from the amortization of the Palisades below-market purchased power agreement, mark-to-market activity, and service revenues.

Some of the agreements to sell the power produced by Entergy Wholesale Commodities’ power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations under the agreements. The Entergy subsidiary is required to provide credit support based upon the difference between the current market prices and contracted power prices in the regions where Entergy Wholesale Commodities sells power. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee.  Cash and letters of credit are also acceptable forms of credit support. At June 30, 2021, based on power prices at that time, Entergy had liquidity exposure of $41 million under the guarantees in place supporting Entergy Wholesale Commodities transactions and $6 million of posted cash collateral. In the event of a decrease in Entergy Corporation’s credit rating to below investment grade, based on power prices as of June 30, 2021, Entergy would have been required to provide approximately $30 million of additional cash or letters of credit under some of the agreements. As of June 30, 2021, the liquidity exposure associated with Entergy Wholesale Commodities assurance requirements, including return of previously posted collateral from counterparties, would increase by an insignificant amount for a $1 per MMBtu increase in gas prices in both the short- and long-term markets.

As of June 30, 2021, substantially all of the credit exposure associated with the planned energy output under contract for the Palisades plant through 2022 is with counterparties or their guarantors that have public investment grade credit ratings.

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of nuclear matters. Following are updates to the discussion in the Form 10-K.

NRC Reactor Oversight Process

As discussed in the Form 10-K, the NRC’s Reactor Oversight Process is a program to collect information about plant performance, assess the information for its safety significance, and provide for appropriate licensee and NRC response. The NRC evaluates plant performance by analyzing two distinct inputs: inspection findings resulting from the NRC’s inspection program and performance indicators reported by the licensee. The evaluations result in the placement of each plant in one of the NRC’s Reactor Oversight Process Action Matrix columns: “licensee response column,” or Column 1, “regulatory response column,” or Column 2, “degraded cornerstone column,” or Column 3, and “multiple/repetitive degraded cornerstone column,” or Column 4. Plants in Column 1 are subject to normal NRC inspection activities. Plants in Column 2, Column 3, or Column 4 are subject to progressively increasing levels of inspection by the NRC with, in general, progressively increasing levels of

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associated costs. Nuclear generating plants owned and operated by Entergy’s Utility and Entergy Wholesale Commodities businesses are currently in Column 1, except for Grand Gulf, which is in Column 3.

In March 2021 the NRC placed Grand Gulf in Column 3 based on the incidence of five unplanned plant scrams during calendar year 2020, some of which were related to upgrades made to the plant’s turbine control system during the spring 2020 refueling outage. The NRC plans to conduct a supplemental inspection of Grand Gulf in accordance with its inspection procedures for nuclear plants in Column 3.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy’s accounting for nuclear decommissioning costs, utility regulatory accounting, impairment of long-lived assets, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See Note 1 to the financial statements in the Form 10-K for discussion of new accounting pronouncements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2021 and 2020
(Unaudited)
			Three Months Ended												Six Months Ended
			2021						2020						2021						2020
			(In Thousands, Except Share Data)
OPERATING REVENUES
Electric			$2,641,375						$2,190,557						$5,179,794						$4,241,196
Natural gas			31,998						22,495						90,166						66,471
Competitive businesses			148,697						199,736						396,947						532,300
TOTAL			2,822,070						2,412,788						5,666,907						4,839,967
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale			626,064						341,005						1,127,231						738,408
Purchased power			252,371						211,961						632,105						428,575
Nuclear refueling outage expenses			43,700						44,894						87,438						95,112
Other operation and maintenance			781,118						736,261						1,487,904						1,438,345
Asset write-offs, impairments, and related charges			342,092						6,775						345,365						11,870
Decommissioning			86,199						95,413						184,841						189,097
Taxes other than income taxes			155,911						158,646						312,613						328,940
Depreciation and amortization			421,545						403,769						836,064						803,478
Other regulatory charges (credits) - net			(55,138)						(25,247)						(22,859)						(32,925)
TOTAL			2,653,862						1,973,477						4,990,702						4,000,900
OPERATING INCOME			168,208						439,311						676,205						839,067
OTHER INCOME
Allowance for equity funds used during construction			16,873						28,370						31,449						64,324
Interest and investment income			71,329						284,823						214,645						67,969
Miscellaneous - net			(62,844)						(93,620)						(123,773)						(70,232)
TOTAL			25,358						219,573						122,321						62,061
INTEREST EXPENSE
Interest expense			220,340						216,799						426,226						422,388
Allowance for borrowed funds used during construction			(6,964)						(12,143)						(12,976)						(27,587)
TOTAL			213,376						204,656						413,250						394,801
INCOME (LOSS) BEFORE INCOME TAXES			(19,810)						454,228						385,276						506,327
Income taxes			(18,416)						89,115						47,526						17,921
CONSOLIDATED NET INCOME (LOSS)			(1,394)						365,113						337,750						488,406
Preferred dividend requirements of subsidiaries			4,580						4,580						9,159						9,159
NET INCOME (LOSS) ATTRIBUTABLE TO ENTERGY CORPORATION			($5,974)						$360,533						$328,591						$479,247
Earnings (loss) per average common share:
Basic			($0.03)						$1.80						$1.64						$2.40
Diluted			($0.03)						$1.79						$1.63						$2.39
Basic average number of common shares outstanding			200,775,395						200,178,010						200,651,162						199,984,013
Diluted average number of common shares outstanding			200,775,395						200,886,749						201,352,830						200,891,134
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three and Six Months Ended June 30, 2021 and 2020
(Unaudited)
			Three Months Ended												Six Months Ended
			2021						2020						2021						2020
			(In Thousands)
Net Income (Loss)			($1,394)						$365,113						$337,750						$488,406
Other comprehensive income (loss)
Cash flow hedges net unrealized loss (net of tax benefit of $66, $6,760, $7,935, and $12,537)			(222)						(25,406)						(29,802)						(47,116)
Pension and other postretirement liabilities (net of tax expense of $6,231, $4,713, $12,545, and $19,789)			22,098						17,224						45,065						71,123
Net unrealized investment gain (loss) (net of tax expense (benefit) of ($27), $10,812, ($25,608), and $19,555)			(108)						18,565						(44,795)						34,309
Other comprehensive income (loss)			21,768						10,383						(29,532)						58,316
Comprehensive Income			20,374						375,496						308,218						546,722
Preferred dividend requirements of subsidiaries			4,580						4,580						9,159						9,159
Comprehensive Income Attributable to Entergy Corporation			$15,794						$370,916						$299,059						$537,563
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2021 and 2020
(Unaudited)
						2021						2020
						(In Thousands)
OPERATING ACTIVITIES
Consolidated net income						$337,750						$488,406
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization						1,150,294						1,131,212
Deferred income taxes, investment tax credits, and non-current taxes accrued						115,274						68,332
Asset write-offs, impairments, and related charges						345,339						11,735
Changes in working capital:
Receivables						(154,277)						(30,990)
Fuel inventory						16,718						(19,897)
Accounts payable						(131,414)						(39,054)
Taxes accrued						(69,711)						44,469
Interest accrued						(162)						4,188
Deferred fuel costs						(286,116)						33,298
Other working capital accounts						(86,774)						(63,943)
Changes in provisions for estimated losses						(54,278)						(37,968)
Changes in other regulatory assets						93,776						74,610
Changes in other regulatory liabilities						170,932						(164,158)
Changes in pension and other postretirement liabilities						(259,593)						(177,224)
Other						(441,211)						125,291
Net cash flow provided by operating activities						746,547						1,448,307
INVESTING ACTIVITIES
Construction/capital expenditures						(2,883,376)						(2,185,294)
Allowance for equity funds used during construction						31,449						64,324
Nuclear fuel purchases						(73,858)						(113,592)
Payment for purchase of plant or assets						(36,534)						(24,633)
Net proceeds from sale of assets						22,421						—
Changes in securitization account						9,685						12,525
Payments to storm reserve escrow account						(17)						(1,965)
Receipts from storm reserve escrow account						44,205						40,589
Decrease in other investments						10,753						2,262
Litigation proceeds for reimbursement of spent nuclear fuel storage costs						15,735						67,252
Proceeds from nuclear decommissioning trust fund sales						3,837,482						1,249,548
Investment in nuclear decommissioning trust funds						(3,804,170)						(1,309,209)
Net cash flow used in investing activities						(2,826,225)						(2,198,193)
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2021 and 2020
(Unaudited)
						2021						2020
						(In Thousands)
FINANCING ACTIVITIES
Proceeds from the issuance of:
Long-term debt						5,008,330						5,201,010
Treasury stock						4,039						41,753
Common stock						26,817						—
Retirement of long-term debt						(2,900,566)						(3,592,919)
Changes in credit borrowings and commercial paper - net						(761,244)						(508)
Other						20,467						(8,448)
Dividends paid:
Common stock						(381,224)						(371,914)
Preferred stock						(9,159)						(9,342)
Net cash flow provided by financing activities						1,007,460						1,259,632
Net increase (decrease) in cash and cash equivalents						(1,072,218)						509,746
Cash and cash equivalents at beginning of period						1,759,099						425,722
Cash and cash equivalents at end of period						$686,881						$935,468
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized						$428,301						$405,248
Income taxes						$27,488						($10,007)
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
June 30, 2021 and December 31, 2020
(Unaudited)
						2021						2020
						(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash						$157,265						$128,851
Temporary cash investments						529,616						1,630,248
Total cash and cash equivalents						686,881						1,759,099
Accounts receivable:
Customer						877,221						833,478
Allowance for doubtful accounts						(109,189)						(117,794)
Other						158,262						135,208
Accrued unbilled revenues						513,710						434,835
Total accounts receivable						1,440,004						1,285,727
Deferred fuel costs						152,230						4,380
Fuel inventory - at average cost						156,216						172,934
Materials and supplies - at average cost						990,088						962,185
Deferred nuclear refueling outage costs						173,365						179,150
Prepayments and other						195,922						196,424
TOTAL						3,794,706						4,559,899
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds						5,238,727						7,253,215
Non-utility property - at cost (less accumulated depreciation)						353,423						343,328
Other						156,766						214,222
TOTAL						5,748,916						7,810,765
PROPERTY, PLANT, AND EQUIPMENT
Electric						61,064,428						59,696,443
Natural gas						631,471						610,768
Construction work in progress						1,383,758						2,012,030
Nuclear fuel						549,166						601,281
TOTAL PROPERTY, PLANT, AND EQUIPMENT						63,628,823						62,920,522
Less - accumulated depreciation and amortization						24,197,413						24,067,745
PROPERTY, PLANT, AND EQUIPMENT - NET						39,431,410						38,852,777
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $83,195 as of June 30, 2021 and $119,238 as of December 31, 2020)						5,982,773						6,076,549
Deferred fuel costs						240,688						240,422
Goodwill						377,172						377,172
Accumulated deferred income taxes						60,749						76,289
Other						312,869						245,339
TOTAL						6,974,251						7,015,771
TOTAL ASSETS						$55,949,283						$58,239,212
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
June 30, 2021 and December 31, 2020
(Unaudited)
						2021						2020
						(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt						$285,324						$1,164,015
Notes payable and commercial paper						866,245						1,627,489
Accounts payable						1,348,734						2,739,437
Customer deposits						390,306						401,512
Taxes accrued						371,300						441,011
Interest accrued						201,629						201,791
Deferred fuel costs						15,111						153,113
Pension and other postretirement liabilities						67,963						61,815
Current portion of unprotected excess accumulated deferred income taxes						64,288						63,683
Other						193,640						206,640
TOTAL						3,804,540						7,060,506
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued						4,375,535						4,361,772
Accumulated deferred investment tax credits						215,828						212,494
Regulatory liability for income taxes-net						1,435,112						1,521,757
Other regulatory liabilities						2,580,823						2,323,851
Decommissioning and asset retirement cost liabilities						4,635,300						6,469,452
Accumulated provisions						188,557						242,835
Pension and other postretirement liabilities						2,587,272						2,853,013
Long-term debt (includes securitization bonds of $113,572 as of June 30, 2021 and $174,635 as of December 31, 2020)						24,211,966						21,205,761
Other						771,993						807,219
TOTAL						41,002,386						39,998,154
Commitments and Contingencies
Subsidiaries' preferred stock without sinking fund						219,410						219,410
EQUITY
Preferred stock, no par value, authorized 1,000,000 shares in 2021 and 0 shares in 2020; issued shares in 2021 and 2020 - none						—						—
Common stock, $.01 par value, authorized 499,000,000 shares; issued 270,300,648 shares in 2021 and 270,035,180 shares in 2020						2,703						2,700
Paid-in capital						6,561,676						6,549,923
Retained earnings						9,844,549						9,897,182
Accumulated other comprehensive loss						(478,739)						(449,207)
Less - treasury stock, at cost (69,347,286 shares in 2021 and 69,790,346 shares in 2020)						5,042,242						5,074,456
Total common shareholders' equity						10,887,947						10,926,142
Subsidiaries' preferred stock without sinking fund						35,000						35,000
TOTAL						10,922,947						10,961,142
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY						$55,949,283						$58,239,212
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
For the Six Months Ended June 30, 2021
(Unaudited)
									Common Shareholders’ Equity
			Subsidiaries’ Preferred Stock						Common Stock						Treasury Stock						Paid-in Capital						Retained Earnings						Accumulated Other Comprehensive Loss						Total
			(In Thousands)
Balance at December 31, 2020			$35,000						$2,700						($5,074,456)						$6,549,923						$9,897,182						($449,207)						$10,961,142
Consolidated net income (a)			4,580						—						—						—						334,565						—						339,145
Other comprehensive loss			—						—						—						—						—						(51,300)						(51,300)
Common stock issuances related to stock plans			—						—						28,235						(29,871)						—						—						(1,636)
Common stock dividends declared			—						—						—						—						(190,595)						—						(190,595)
Preferred dividend requirements of subsidiaries (a)			(4,580)						—						—						—						—						—						(4,580)
Balance at March 31, 2021			$35,000						$2,700						($5,046,221)						$6,520,052						$10,041,152						($500,507)						$11,052,176
Consolidated net income (loss) (a)			4,580						—						—						—						(5,974)						—						(1,394)
Other comprehensive income			—						—						—						—						—						21,768						21,768
Common stock issuances and sales under the at the market equity distribution program			—						3						—						28,213						—						—						28,216
Common stock issuance costs			—						—						—						(1,399)						—						—						(1,399)
Common stock issuances related to stock plans			—						—						3,979						14,810						—						—						18,789
Common stock dividends declared			—						—						—						—						(190,629)						—						(190,629)
Preferred dividend requirements of subsidiaries (a)			(4,580)						—						—						—						—						—						(4,580)
Balance at June 30, 2021			$35,000						$2,703						($5,042,242)						$6,561,676						$9,844,549						($478,739)						$10,922,947
See Notes to Financial Statements.
(a) Consolidated net income (loss) and preferred dividend requirements of subsidiaries for first quarter 2021 and second quarter 2021 each includes $4.1 million of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented as equity.

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CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
For the Six Months Ended June 30, 2020
(Unaudited)
									Common Shareholders’ Equity
			Subsidiaries' Preferred Stock						Common Stock						Treasury Stock						Paid-in Capital						Retained Earnings						Accumulated Other Comprehensive Loss						Total
			(In Thousands)
Balance at December 31, 2019			$35,000						$2,700						($5,154,150)						$6,564,436						$9,257,609						($446,920)						$10,258,675
Implementation of accounting standards			—						—						—						—						(419)						—						(419)
Balance at January 1, 2020			35,000						2,700						(5,154,150)						6,564,436						9,257,190						(446,920)						10,258,256
Consolidated net income (a)			4,580						—						—						—						118,714						—						123,294
Other comprehensive income			—						—						—						—						—						47,933						47,933
Common stock issuances related to stock plans			—						—						73,580						(53,753)						—						—						19,827
Common stock dividends declared			—						—						—						—						(185,763)						—						(185,763)
Preferred dividend requirements of subsidiaries (a)			(4,580)						—						—						—						—						—						(4,580)
Balance at March 31, 2020			$35,000						$2,700						($5,080,570)						$6,510,683						$9,190,141						($398,987)						$10,258,967
Consolidated net income (a)			4,580						—						—						—						360,533						—						365,113
Other comprehensive income			—						—						—						—						—						10,383						10,383
Common stock issuances related to stock plans			—						—						3,609						13,647						—						—						17,256
Common stock dividends declared			—						—						—						—						(186,151)						—						(186,151)
Preferred dividend requirements of subsidiaries (a)			(4,580)						—						—						—						—						—						(4,580)
Balance at June 30, 2020			$35,000						$2,700						($5,076,961)						$6,524,330						$9,364,523						($388,604)						$10,460,988
(a) Consolidated net income and preferred dividend requirements of subsidiaries for first quarter 2020 and second quarter 2020 each includes $4.1 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

(Unaudited)

NOTE 1.  COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, 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 with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

ANO Damage, Outage, and NRC Reviews

See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation.

In January 2021 the U.S. Court of Federal Claims issued a final judgment in the amount of $23.1 million in favor of Entergy Nuclear Palisades and against the DOE in the second round Palisades damages case. Entergy received payment from the U.S. Treasury in February 2021. The effects of recording the judgment were reductions to plant, other operation and maintenance expense, and taxes other than income taxes. The Palisades damages awarded included $15.7 million related to costs previously recorded as plant, $7.1 million related to costs previously recorded as other operation and maintenance expenses, and $0.3 million related to costs previously recorded as taxes other than income taxes. Of the $15.7 million previously recorded as plant, Entergy recorded $9.1 million as a reduction to previously-recorded depreciation expense.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

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Notes to Financial Statements

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.

Grand Gulf-Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements.

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

Regulatory Assets and Regulatory Liabilities

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff.

Entergy Louisiana

In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over five months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. The final amount of incremental fuel costs is subject to change through the MISO resettlement process. At its April 2021 meeting, the LPSC authorized its staff to review the prudence of the February 2021 fuel costs incurred by all LPSC-jurisdictional utilities. At its June 2021 meeting, the LPSC approved the hiring of consultants to assist its staff in this review. Discovery is ongoing.

In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed.

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Notes to Financial Statements

Entergy Texas

In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules.

Retail Rate Proceedings

See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies.  The following are updates to that discussion.

Filings with the APSC (Entergy Arkansas)

Retail Rates

2020 Formula Rate Plan Filing

As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021 the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021, Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019. In June 2021, Entergy Arkansas filed another compliance tariff in its formula rate plan proceeding to effectuate the additional provisions of Act 894, and the APSC approved the second compliance tariff filing in July 2021.

2021 Formula Rate Plan Filing

In July 2021, Entergy Arkansas filed with the APSC its 2021 formula rate plan filing to set its formula rate for the 2022 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2022 and a netting adjustment for the historical year 2020. The filing showed that Entergy Arkansas’s earned rate

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Notes to Financial Statements

of return on common equity for the 2022 projected year is 7.65% resulting in a revenue deficiency of $89.2 million. The earned rate of return on common equity for the 2020 historical year was 7.92% resulting in a $19.4 million netting adjustment. The total proposed revenue change for the 2022 projected year and 2020 historical year netting adjustment is $108.7 million. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase is limited to $72.6 million. An order is requested by December 2021.

COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of June 30, 2021, Entergy Arkansas recorded a regulatory asset of $11.2 million for costs associated with the COVID-19 pandemic.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2017 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC staff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. In July 2021 the LPSC approved a settlement between LPSC staff and Entergy Louisiana finding that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers.

Request for Extension and Modification of Formula Rate Plan

As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. In May 2021 the LPSC approved the uncontested settlement. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees.

2020 Formula Rate Plan Filing

In June 2021, Entergy Louisiana filed its formula rate plan evaluation report for its 2020 calendar year operations. The 2020 test year evaluation report produced an earned return on common equity of 8.45%, with a base formula rate plan revenue increase of $63 million. Certain reductions in formula rate plan revenue driven by lower sales volumes, reductions in capacity cost and net MISO cost, and higher credits resulting from the Tax Cuts

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Notes to Financial Statements

and Jobs Act offset the base formula rate plan revenue increase, leading to a net increase in formula rate plan revenue of $50.7 million. The report also included multiple new adjustments to account for, among other things, the calculation of distribution recovery mechanism revenues. The effects of the changes to total formula rate plan revenue are different for each legacy company, primarily due to differences in the legacy companies’ capacity cost changes, including the effect of true-ups. Legacy Entergy Louisiana formula rate plan revenues will increase by $27 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $23.7 million. Subject to refund and LPSC review, the resulting changes will become effective for bills rendered during the first billing cycle of September 2021. Discovery is underway, and parties are required to file any objections to the formula rate plan revenue requirement by September 20, 2021. Entergy Louisiana’s response to any objections is due October 30, 2021. Should the parties be unable to resolve any objections, those issues will be set for hearing, with recovery of the associated costs subject to refund.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. The suspension of late fees and disconnects for non-payment was approved through the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of June 30, 2021, Entergy Louisiana recorded a regulatory asset of $54.7 million for costs associated with the COVID-19 pandemic.

Filings with the MPSC (Entergy Mississippi)

2021 Formula Rate Plan Filing

In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2021 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments.

In June 2021, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2021 test year filing that resulted in a total rate increase of $48.2 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2020 look-back filing reflected an earned return on rate base of 6.12% in calendar year 2020, which is below the look-back bandwidth, resulting in a $17.5 million increase in formula rate plan

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Notes to Financial Statements

revenues on an interim basis through May 2021. This includes $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. See “COVID-19 Orders” below for additional discussion of provisions of the joint stipulation related to COVID-19 expenses. In June 2021 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2021. In June 2021, Entergy Mississippi recorded regulatory assets of $19.9 million to reflect the effects of the joint stipulation.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 pandemic compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. Pursuant to the June 2021 MPSC order approving Entergy Mississippi’s 2021 formula rate plan filing, Entergy Mississippi stopped deferring COVID-19 non-bad debt expenses effective December 31, 2020 and will include those expenses in the look-back filing for the 2021 formula rate plan test year. In the order, the MPSC also adopted Entergy Mississippi’s quantification and methodology for calculating COVID-19 incremental bad debt expenses and authorized Entergy Mississippi to continue deferring these bad debt expenses through December 2021. As of June 30, 2021, Entergy Mississippi recorded a regulatory asset of $19.3 million for costs associated with the COVID-19 pandemic.

Filings with the City Council (Entergy New Orleans)

2021 Formula Rate Plan Filing

In July 2021, Entergy New Orleans submitted to the City Council its formula rate plan 2020 test year filing. The 2020 test year evaluation report produced an earned return on equity of 6.26% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $64 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $40 million and an increase in authorized gas revenues of $18.8 million. Entergy New Orleans also seeks to commence collecting $5.2 million in electric revenues and $0.3 million in gas revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of November 2021 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a litigated procedural schedule that would extend the process for City Council approval of disputed rate adjustments into 2022.

COVID-19 Orders

As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of June 30, 2021, the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program.

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Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021, which was not extended by the City Council. As of June 30, 2021, Entergy New Orleans recorded a regulatory asset of $13.8 million for costs associated with the COVID-19 pandemic.

Filings with the PUCT and Texas Cities (Entergy Texas)

Distribution Cost Recovery Factor (DCRF) Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s then-effective DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s agreed motion for interim rates, which went into effect in March 2021. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding. In May 2021 the PUCT issued an order approving the settlement.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting. In June 2021 the PUCT issued an order approving the settlement.

COVID-19 Orders

As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of June 30, 2021, Entergy Texas recorded a regulatory asset of $14.2 million for costs associated with the COVID-19 pandemic.

Generation Cost Recovery Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31,

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2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million, with the ability to seek recovery of a majority of the remaining requested costs in a subsequent rate case. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the administrative law judge issued an order unabating the proceeding and in May 2021 the administrative law judge issued an order finding Entergy Texas’s application and notice of the application to be sufficient. In May 2021, Entergy Texas filed an amendment to the application to reflect the PUCT’s approval of the sale of a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc., which closed in June 2021. In June 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. In July 2021 the administrative law judge with the State Office of Administrative Hearings adopted a procedural schedule setting a hearing on the merits for September 2021. In July 2021 the parties filed a motion to abate the procedural schedule noting they had reached an agreement in principle and to allow the parties time to finalize a settlement agreement, which motion was granted by the administrative law judge.

In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. See Note 14 to the financial statements herein for further discussion of the Hardin County Peaking Facility purchase.

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, the FERC’s opportunity sales orders have been appealed to the D.C. Circuit. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders.

As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. In September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and in June 2021 the court stayed all discovery until it rules on pending motions, after which the court will issue an amended schedule if necessary.

Complaints Against System Energy

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020.

In March 2021 the FERC ALJ issued an initial decision. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that

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the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $59 million, which includes interest through June 30, 2021, and the estimated resulting annual rate reduction would be approximately $46 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $37 million, including interest, as of June 30, 2021.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021, the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through June 30, 2021, is approximately $422 million, plus interest, which is approximately $119 million through June 30, 2021. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through June 30, 2021.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in

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whole or in part. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

Also as discussed in the Form 10-K, in November 2020 the IRS issued a Revenue Agent’s Report (RAR) for the 2014/2015 tax year and in December 2020 Entergy executed it. The RAR contained an adjustment to System Energy’s uncertain nuclear decommissioning tax position. As a result of the RAR, in December 2020, System Energy filed amendments to its new Federal Power Act section 205 filings to establish an ongoing rate base credit for the accumulated deferred income taxes resulting from the decommissioning uncertain tax position and to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendments both propose the inclusion of the RAR as support for the filings. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendments, reiterating their prior objections to the filings. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filings subject to refund, setting them for hearing, and holding the hearing in abeyance.

In December 2020, System Energy filed a new Federal Power Act section 205 filing to provide a one-time, historical credit to customers of $25.2 million for the accumulated deferred income taxes that would have been created by the decommissioning uncertain tax position if the IRS’s decision had been known in 2016. In January 2021 the LPSC, APSC, MPSC, and City Council filed a protest to the filing. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. The one-time credit was made during the first quarter 2021.

LPSC Authorization of Additional Complaints

As discussed in the Form 10-K, in May 2020 the LPSC authorized its staff to file additional complaints at the FERC related to the rates charged by System Energy for Grand Gulf energy and capacity supplied to Entergy Louisiana under the Unit Power Sales Agreement. The LPSC directive notes that the initial decision issued by the presiding ALJ in the Grand Gulf sale-leaseback complaint proceeding did not address, for procedural reasons, certain rate issues raised by the LPSC and declined to order further investigation of rates charged by System Energy. The LPSC directive authorizes its staff to file complaints at the FERC “necessary to address these rate issues, to request a full investigation into the rates charged by System Energy for Grand Gulf power, and to seek rate refund, rate reduction, and such other remedies as may be necessary and appropriate to protect Louisiana ratepayers.” The LPSC directive further stated that the LPSC has seen “information suggesting that the Grand Gulf plant has been significantly underperforming compared to other nuclear plants in the United States, has had several extended and unexplained outages, and has been plagued with serious safety concerns.” The LPSC expressed concern that the costs paid by Entergy Louisiana's retail customers may have been detrimentally impacted, and authorized “the filing of a FERC complaint to address these performance issues and to seek appropriate refund, rate reduction, and other remedies as may be appropriate.”

Unit Power Sales Agreement Complaint

The first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The first complaint raises two sets of rate allegations: violations of the filed rate and a corresponding request for refunds for prior periods; and elements of the Unit Power Sales Agreement are unjust and unreasonable and a corresponding request for refunds for the 15-month refund period and changes to the Unit Power Sales Agreement prospectively. In May 2021 the FERC issued an order addressing the complaint, establishing a refund effective date of September 21, 2020, establishing hearing procedures, and holding those procedures in abeyance pending the FERC’s review of the initial decision in the Grand Gulf sale-leaseback renewal complaint discussed above. System Energy agreed that the hearing should be held in abeyance but sought rehearing of the FERC’s decision as related to matters set for hearing that were beyond the scope of the FERC’s jurisdiction or authority. The complainants sought rehearing of the FERC’s decision to hold the hearing in abeyance and filed a motion to proceed, which motion System Energy subsequently opposed. In June 2021, System Energy’s request for rehearing was denied by operation of law, and System Energy filed an appeal of the FERC’s orders in the Court of

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Appeals for the Fifth Circuit. The appeal is currently in abeyance.

Grand Gulf Prudence Complaint

The second of the additional complaints was filed at the FERC in March 2021 by the LPSC, the APSC, and the City Council against System Energy, Entergy Services, Entergy Operations, and Entergy Corporation. The second complaint contains two primary allegations. First, it alleges that, based on the plant’s capacity factor and alleged safety performance, System Energy and the other respondents imprudently operated Grand Gulf during the period 2016-2020, and it seeks refunds of at least $360 million in alleged replacement energy costs, in addition to other costs, including those that can only be identified upon further investigation. Second, it alleges that the performance and/or management of the 2012 extended power uprate of Grand Gulf was imprudent, and it seeks refunds of all costs of the 2012 uprate that are determined to result from imprudent planning or management of the project. In addition to the requested refunds, the complaint asks that the FERC modify the Unit Power Sales Agreement to provide for full cost recovery only if certain performance indicators are met and to require pre-authorization of capital improvement projects in excess of $125 million before related costs may be passed through to customers in rates. In April 2021, System Energy and the other respondents filed their motion to dismiss and answer to the complaint. System Energy requested that the FERC dismiss the claims within the complaint. With respect to the claim concerning operations, System Energy argues that the complaint does not meet its legal burden because, among other reasons, it fails to allege any specific imprudent conduct. With respect to the claim concerning the uprate, System Energy argues that the complaint fails because, among other reasons, the complainants’ own conduct prevents them from raising a serious doubt as to the prudence of the uprate. System Energy also requests that the FERC dismiss other elements of the complaint, including the proposed modifications to the Unit Power Sales Agreement, because they are not warranted. Additional responsive pleadings were filed by the complainants and System Energy during the period from March through July 2021.

Storm Cost Filings with Retail Regulators

Entergy Louisiana

Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri

In August 2020 and October 2020, Hurricane Laura, Hurricane Delta, and Hurricane Zeta caused significant damage to portions of Entergy Louisiana’s service area. The storms resulted in widespread outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the outages. Additionally, as a result of Hurricane Laura’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild.

In October 2020, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta. Subsequently, Entergy Louisiana and the LPSC staff filed a joint motion seeking approval to exclude from the derivation of Entergy Louisiana’s capital structure and cost rate of debt for ratemaking purposes, including the allowance for funds used during construction, shorter-term debt up to $1.1 billion issued by Entergy Louisiana to fund costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta costs on an interim basis. In November 2020 the LPSC issued an order approving the joint motion, and Entergy Louisiana issued $1.1 billion of 0.62% Series mortgage bonds due November 2023. Also in November 2020, Entergy Louisiana drew $257 million from its funded storm reserves.

In February 2021, two winter storms (collectively, Winter Storm Uri) brought freezing rain and ice to Louisiana. Ice accumulation sagged or downed trees, limbs, and power lines, causing damage to Entergy Louisiana’s transmission and distribution systems. The additional weight of ice caused trees and limbs to fall into power lines and other electric equipment. When the ice melted, it affected vegetation and electrical equipment, causing incremental outages. As discussed above in “Fuel and purchased power recovery,” Entergy Louisiana is

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recovering the incremental fuel costs associated with Winter Storm Uri over a five-month period from April 2021 through August 2021.

In April 2021, Entergy Louisiana filed an application with the LPSC relating to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, and in July 2021, Entergy Louisiana made a supplemental filing updating the total restoration costs. Total restoration costs, as included in the July 2021 supplemental filing, for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by the storms are currently estimated to be approximately $2.06 billion, including approximately $1.68 billion in capital costs and approximately $380 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana is seeking an LPSC determination that $2.11 billion was prudently incurred and, therefore, is eligible for recovery from customers. Additionally, Entergy Louisiana is requesting that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million is appropriate. In June 2021 a procedural schedule was established with a hearing in January 2022. In July 2021, Entergy Louisiana supplemented the application with a request regarding the financing and recovery of the recoverable storm restoration costs. Specifically, Entergy Louisiana requested approval to securitize its restoration costs pursuant to Louisiana Act 55 financing, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021. In total, Entergy Louisiana requested authorization for the issuance of system restoration bonds in one or more series in an aggregate principal amount of $2.18 billion, which includes the costs of re-establishing and funding a storm damage escrow account, carrying costs and unamortized debt costs on interim financing, and issuance costs.

Entergy New Orleans

Hurricane Zeta

In October 2020, Hurricane Zeta caused significant damage to Entergy New Orleans’s service area. The storm resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the power outages. In March 2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. In May 2021, Entergy New Orleans filed an application with the City Council requesting approval and certification that its system restoration costs associated with Hurricane Zeta of approximately $36 million, including approximately $28 million in capital costs and approximately $8 million in non-capital costs, were reasonable and necessary to enable Entergy New Orleans to restore electric service to its customers and Entergy New Orleans’s electric utility infrastructure. Additionally, Entergy New Orleans plans to make a separate filing at an appropriate time to the City Council requesting replenishment of its storm reserves.

Entergy Texas

Hurricane Laura, Hurricane Delta, and Winter Storm Uri

In August 2020 and October 2020, Hurricane Laura and Hurricane Delta caused extensive damage to Entergy Texas’s service area. In February 2021, Winter Storm Uri also caused damage to Entergy Texas’s service area. The storms resulted in widespread power outages, significant damage primarily to distribution and transmission infrastructure, and the loss of sales during the power outages. In April 2021, Entergy Texas filed an application with the PUCT requesting a determination that its system restoration costs associated with Hurricane Laura, Hurricane Delta, and Winter Storm Uri of approximately $250 million, including approximately $200 million in capital costs and approximately $50 million in non-capital costs were reasonable and necessary to enable Entergy Texas to restore electric service to its customers and Entergy Texas’s electric utility infrastructure. The filing currently includes only a portion of the Winter Storm Uri costs. In July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of the system restoration costs that are the subject of the April 2021 application. As stated in the July 2021 application, Entergy Texas also plans to seek a separate financing order, in a separate application and docket, under the newly-enacted Subchapter J of Chapter 36 of the Public Utility Regulatory Act, titled “Lower-Cost Financing Mechanism for Securitization for Recovery of System Restoration Costs.” However, the ability to timely utilize that mechanism for securitization of the system

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restoration costs that are approved for recovery is dependent on certain events outside of Entergy Texas’s control, which may necessitate utilizing the traditional structure for securitization of the system restoration costs as may be approved for recovery in the proceeding initiated in July 2021. In either event, only one financing order would ultimately be utilized for the securitization of system restoration costs approved for recovery by the PUCT. A procedural schedule was established with a hearing on the merits in September 2021.

NOTE 3.  EQUITY (Entergy Corporation and Entergy Louisiana)

Common Stock

Earnings (Loss) per Share

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

			For the Three Months Ended June 30,
			2021																		2020
			(In Millions, Except Per Share Data)
			Income						Shares						$/share						Income						Shares						$/share
Basic earnings (loss) per share
Net income (loss) attributable to Entergy Corporation			($6.0)						200.8						($0.03)						$360.5						200.2						$1.80
Average dilutive effect of:
Stock options									—						—												0.3						—
Other equity plans									—						—												0.4						(0.01)
Diluted earnings (loss) per share			($6.0)						200.8						($0.03)						$360.5						200.9						$1.79

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1 million for the three months ended June 30, 2021 and approximately 0.5 million for the three months ended June 30, 2020.

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

			For the Six Months Ended June 30,
			2021																		2020
			(In Millions, Except Per Share Data)
			Income						Shares						$/share						Income						Shares						$/share
Basic earnings per share
Net income attributable to Entergy Corporation			$328.6						200.7						$1.64						$479.2						200.0						$2.40
Average dilutive effect of:
Stock options									0.4						(0.01)												0.5						(0.01)
Other equity plans									0.3						—												0.4						—
Diluted earnings per share			$328.6						201.4						$1.63						$479.2						200.9						$2.39

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1 million for the six months ended June 30, 2021 and approximately 0.5 million for the six months ended June 30, 2020.

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Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K.

Dividends declared per common share were $0.95 for the three months ended June 30, 2021 and $0.93 for the three months ended June 30, 2020. Dividends declared per common share were $1.90 for the six months ended June 30, 2021 and $1.86 for the six months ended June 30, 2020.

Equity Distribution Program

In January 2021, Entergy entered into an equity distribution sales agreement with several counterparties establishing an at the market equity distribution program, pursuant to which Entergy may offer and sell from time to time shares of its common stock. The sales agreement provides that, in addition to the issuance and sale of shares of Entergy common stock, Entergy may enter into forward sale agreements for the sale of its common stock. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $1 billion.

During the six months ended June 30, 2021, Entergy Corporation issued 265,468 shares of common stock under the at the market equity distribution program. The net sales proceeds from these shares totaled $26.8 million, which includes the gross sales price of $28.2 million received by Entergy Corporation less $1.1 million of general issuance costs and $0.3 million of aggregate compensation to the agents with respect to such sales.

In June 2021, Entergy entered into a forward sale agreement for 416,853 shares of common stock. No amounts have or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the equity forward sale agreement occur. The forward sale agreement requires Entergy to, at its election prior to September 30, 2022, either (i) physically settle the transactions by issuing the total of 416,853 shares of its common stock to the investment bank in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially $106.87 per share) or (ii) net settle the transaction in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreement. In connection with the forward sale agreement, the forward seller, or its affiliates, borrowed from third parties and sold 416,853 shares of Entergy Corporation’s common stock. The gross sales price of these shares totaled $45 million with aggregate compensation to the agents of $0.5 million. Entergy Corporation did not receive any proceeds from such sales of borrowed shares.

Until settlement of the forward sale agreement, earnings per share dilution resulting from the agreement, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Entergy’s common stock is higher than the average forward sales price. For the three and six months ended June 30, 2021, shares under the forward sale agreement were not included in the calculation of diluted common shares outstanding because their effect would have been antidilutive.

Treasury Stock

During the six months ended June 30, 2021, Entergy Corporation issued 443,060 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards.  Entergy Corporation did not repurchase any of its common stock during the six months ended June 30, 2021.

Retained Earnings

On July 30, 2021, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.95 per share, payable on September 1, 2021, to holders of record as of August 12, 2021.

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Comprehensive Income

Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 30, 2021 by component:

			Cash flow hedges net unrealized gain (loss)						Pension and other postretirement liabilities						Net unrealized investment gain (loss)						Total Accumulated Other Comprehensive Income (Loss)
			(In Thousands)
Beginning balance, April 1, 2021			($861)						($511,609)						$11,963						($500,507)
Other comprehensive income (loss) before reclassifications			(14)						—						648						634
Amounts reclassified from accumulated other comprehensive income (loss)			(208)						22,098						(756)						21,134
Net other comprehensive income (loss) for the period			(222)						22,098						(108)						21,768
Ending balance, June 30, 2021			($1,083)						($489,511)						$11,855						($478,739)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 30, 2020 by component:

			Cash flow hedges net unrealized gain (loss)						Pension and other postretirement liabilities						Net unrealized investment gain (loss)												Total Accumulated Other Comprehensive Income (Loss)
			(In Thousands)
Beginning balance, April 1, 2020			$62,496						($503,173)						$41,690												($398,987)
Other comprehensive income (loss) before reclassifications			4,890						—						22,545												27,435
Amounts reclassified from accumulated other comprehensive income (loss)			(30,296)						17,224						(3,980)												(17,052)
Net other comprehensive income (loss) for the period			(25,406)						17,224						18,565												10,383
Ending balance, June 30, 2020			$37,090						($485,949)						$60,255												($388,604)

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The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2021 by component:

			Cash flow hedges net unrealized gain (loss)						Pension and other postretirement liabilities						Net unrealized investment gain (loss)						Total Accumulated Other Comprehensive Income (Loss)
			(In Thousands)
Beginning balance, January 1, 2021			$28,719						($534,576)						$56,650						($449,207)
Other comprehensive income (loss) before reclassifications			1,467						—						(44,653)						(43,186)
Amounts reclassified from accumulated other comprehensive income (loss)			(31,269)						45,065						(142)						13,654
Net other comprehensive income (loss) for the period			(29,802)						45,065						(44,795)						(29,532)
Ending balance, June 30, 2021			($1,083)						($489,511)						$11,855						($478,739)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2020 by component:

			Cash flow hedges net unrealized gain (loss)						Pension and other postretirement liabilities						Net unrealized investment gain (loss)												Total Accumulated Other Comprehensive Income (Loss)
			(In Thousands)
Beginning balance, January 1, 2020			$84,206						($557,072)						$25,946												($446,920)
Other comprehensive income (loss) before reclassifications			97,373						34,349						40,258												171,980
Amounts reclassified from accumulated other comprehensive income (loss)			(144,489)						36,774						(5,949)												(113,664)
Net other comprehensive income (loss) for the period			(47,116)						71,123						34,309												58,316
Ending balance, June 30, 2020			$37,090						($485,949)						$60,255												($388,604)

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The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended June 30, 2021 and 2020:

						Pension and Other Postretirement Liabilities
						2021						2020
						(In Thousands)
Beginning balance, April 1,						$3,920						$14,029
Amounts reclassified from accumulated other comprehensive income (loss)						588						(945)
Net other comprehensive income (loss) for the period						588						(945)
Ending balance, June 30,						$4,508						$13,084

The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the six months ended June 30, 2021 and 2020:

						Pension and Other Postretirement Liabilities
						2021						2020
						(In Thousands)
Beginning balance, January 1,						$4,327						$4,562
Other comprehensive income (loss) before reclassifications						—						10,050
Amounts reclassified from accumulated other comprehensive income (loss)						181						(1,528)
Net other comprehensive income (loss) for the period						181						8,522
Ending balance, June 30,						$4,508						$13,084

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Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended June 30, 2021 and 2020 were as follows:

			Amounts reclassified from AOCI												Income Statement Location
			2021						2020
			(In Thousands)
Cash flow hedges net unrealized gain (loss)
Power contracts			$312						$25,086						Competitive business operating revenues
Interest rate swaps			(48)						(48)						Miscellaneous - net
Total realized gain (loss) on cash flow hedges			264						25,038
Income taxes			(56)						5,258						Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)			$208						$30,296
Pension and other postretirement liabilities
Amortization of prior-service credit			$5,248						$5,682						(a)
Amortization of loss			(27,534)						(27,619)						(a)
Settlement loss			(6,043)						—						(a)
Total amortization			(28,329)						(21,937)
Income taxes			6,231						4,713						Income taxes
Total amortization (net of tax)			($22,098)						($17,224)
Net unrealized investment gain (loss)
Realized gain (loss)			$1,196						$6,297						Interest and investment income
Income taxes			(440)						(2,317)						Income taxes
Total realized investment gain (loss) (net of tax)			$756						$3,980
Total reclassifications for the period (net of tax)			($21,134)						$17,052

(a)These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

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Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the six months ended June 30, 2021 and 2020 were as follows:

			Amounts reclassified from AOCI												Income Statement Location
			2021						2020
			(In Thousands)
Cash flow hedges net unrealized gain (loss)
Power contracts			$39,679						$119,509						Competitive business operating revenues
Interest rate swaps			(97)						(97)						Miscellaneous - net
Total realized gain (loss) on cash flow hedges			39,582						119,412
Income taxes			(8,313)						25,077						Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)			$31,269						$144,489
Pension and other postretirement liabilities
Amortization of prior-service credit			$10,496						$9,401						(a)
Amortization of loss			(62,063)						(54,937)						(a)
Settlement loss			(6,043)						—						(a)
Total amortization			(57,610)						(45,536)
Income taxes			12,545						8,762						Income taxes
Total amortization (net of tax)			($45,065)						($36,774)
Net unrealized investment gain (loss)
Realized gain (loss)			$224						$9,413						Interest and investment income
Income taxes			(82)						(3,464)						Income taxes
Total realized investment gain (loss) (net of tax)			$142						$5,949
Total reclassifications for the period (net of tax)			($13,654)						$113,664

(a)These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

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Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended June 30, 2021 and 2020 were as follows:

						Amounts reclassified from AOCI												Income Statement Location
						2021						2020
						(In Thousands)
Pension and other postretirement liabilities
Amortization of prior-service credit						$1,230						$1,698						(a)
Amortization of loss						(626)						(419)						(a)
Settlement loss						(1,400)						—						(a)
Total amortization						(796)						1,279
Income taxes						208						(334)						Income taxes
Total amortization (net of tax)						(588)						945
Total reclassifications for the period (net of tax)						($588)						$945

(a)These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the six months ended June 30, 2021 and 2020 were as follows:

						Amounts reclassified from AOCI												Income Statement Location
						2021						2020
						(In Thousands)
Pension and other postretirement liabilities
Amortization of prior-service credit						$2,460						$2,787						(a)
Amortization of loss						(1,305)						(720)						(a)
Settlement loss						(1,400)						—						(a)
Total amortization						(245)						2,067
Income taxes						64						(539)						Income taxes
Total amortization (net of tax)						(181)						1,528
Total reclassifications for the period (net of tax)						($181)						$1,528

(a)These accumulated other comprehensive income (loss) components were included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

Preferred Stock

In May 2021, Entergy’s certificate of incorporation was amended and restated to provide authority to issue up to 1,000,000 shares of preferred stock, no par value per share, and to decrease from 500,000,000 to 499,000,000 the number of shares of common stock, par value of $0.01 per share, authorized for issuance. As of June 30, 2021, no preferred stock has been issued under the new authority.

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

Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in June 2026.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment 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 six months ended June 30, 2021 was 1.61% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2021.

Capacity						Borrowings						Letters of Credit						Capacity Available
(In Millions)
$3,500						$150						$6						$3,344

Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, 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 Registrant Subsidiaries (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 Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  As of June 30, 2021, Entergy Corporation had approximately $866 million of commercial paper outstanding.  The weighted-average interest rate for the six months ended June 30, 2021 was 0.32%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2021 as follows:

Company						Expiration Date						Amount of Facility						Interest Rate (a)						Amount Drawn as of June 30, 2021						Letters of Credit Outstanding as of June 30, 2021
Entergy Arkansas						April 2022						$25 million (b)						2.75%						$—						$—
Entergy Arkansas						June 2026						$150 million (c)						1.23%						$—						$—
Entergy Louisiana						June 2026						$350 million (c)						1.23%						$—						$—
Entergy Mississippi						April 2022						$37.5 million (d)						1.60%						$—						$—
Entergy Mississippi						April 2022						$35 million (d)						1.60%						$—						$—
Entergy Mississippi						April 2022						$10 million (d)						1.60%						$—						$—
Entergy New Orleans						June 2024						$25 million (c)						1.58%						$—						$—
Entergy Texas						June 2026						$150 million (c)						1.60%						$—						$1.3 million

(a)The interest rate is the estimated interest rate as of June 30, 2021 that would have been applied to outstanding borrowings under the facility.

(b)Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

(d)Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

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The commitment fees on the credit facilities range from 0.075% to 0.275% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities primarily as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2021:

Company

Amount of Uncommitted Facility

Letter of Credit Fee

MISO Letters of Credit Issued as of June 30, 2021 (a) (b)

Entergy Arkansas

$25 million

0.78%

$2.5 million

Entergy Louisiana

$125 million

0.78%

$7.8 million

Entergy Mississippi

$65 million

0.78%

$2 million

Entergy New Orleans

$15 million

1.00%

$1 million

Entergy Texas

$50 million

0.70%

$18.2 million

(a)As of June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.

(b)As of June 30, 2021, in addition to the $2 million MISO letter of credit, Entergy Mississippi has $7.9 million of non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy are effective through July 14, 2022. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements.  The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following were the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2021 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

			Authorized						Borrowings
			(In Millions)
Entergy Arkansas			$250						$—
Entergy Louisiana			$450						$—
Entergy Mississippi			$175						$17
Entergy New Orleans			$150						$38
Entergy Texas			$200						$63
System Energy			$200						$—

Vermont Yankee Credit Facility (Entergy Corporation)

In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Entergy Assets Management Operations, LLC (formerly Vermont Yankee Asset Retirement, LLC),

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Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in December 2022. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of June 30, 2021, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the six months ended June 30, 2021 was 1.71% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar.

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

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of June 30, 2021:

Company						Expiration Date						Amount of Facility						Weighted  Average Interest  Rate on  Borrowings (a)						Amount Outstanding as of June 30, 2021
												(Dollars in Millions)
Entergy Arkansas VIE						June 2024						$80						1.26%						$—
Entergy Louisiana River Bend VIE						June 2024						$105						1.22%						$64.6
Entergy Louisiana Waterford VIE						June 2024						$105						1.22%						$62.1
System Energy VIE						June 2024						$120						1.22%						$45.7

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization.

The nuclear fuel company variable interest entities had notes payable that were included in debt on the respective balance sheets as of June 30, 2021 as follows:

Company

Description

Amount

Entergy Arkansas VIE

3.65% Series L due July 2021 (a)

$90 million

Entergy Arkansas VIE

3.17% Series M due December 2023

$40 million

Entergy Arkansas VIE

1.84% Series N due July 2026

$90 million

Entergy Louisiana River Bend VIE

2.51% Series V due June 2027

$70 million

Entergy Louisiana Waterford VIE

3.22% Series I due December 2023

$20 million

System Energy VIE

2.05% Series K due September 2027

$90 million

(a)    Repaid at maturity

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

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Entergy Arkansas, Entergy Louisiana, and System Energy each have obtained financing authorizations from the FERC that extend through July 14, 2022 for issuances by its nuclear fuel company variable interest entities.

Debt Issuances and Retirements

(Entergy Corporation)

In March 2021, Entergy Corporation issued $650 million of 1.90% Series senior notes due June 2028 and $650 million of 2.40% Series senior notes due June 2031. Entergy Corporation used the proceeds to repay a portion of its outstanding commercial paper and for general corporate purposes.

(Entergy Arkansas)

In March 2021, Entergy Arkansas issued $400 million of 3.35% Series mortgage bonds due June 2052. Entergy Arkansas expects to use, or has used, the proceeds, together with other funds, to finance in part the purchase of the Searcy Solar Facility, to repay a portion of the debt outstanding under its $150 million long-term revolving credit facility, to repay a portion of the debt outstanding under its $25 million short-term revolving credit facility, and for general corporate purposes.

(Entergy Louisiana)

In March 2021, Entergy Louisiana issued $500 million of 2.35% Series mortgage bonds due June 2032 and $500 million of 3.10% Series mortgage bonds due June 2041. Entergy Louisiana used the proceeds, together with other funds, to repay at maturity, its $200 million of 4.80% Series mortgage bonds due May 2021, to finance, on an interim basis, storm restoration costs related to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and the winter storms of February 2021, and for general corporate purposes.

In April 2021, Entergy Louisiana arranged for the issuance by the Louisiana Local Government Environmental Facilities and Community Development Authority of (i) $16.2 million of 2.00% pollution control revenue bonds Series 2021A due June 2030, and (ii) $182.48 million of 2.50% pollution control revenue bonds Series 2021B due April 2036, each of which series is evidenced by a separate series of collateral trust mortgage bonds of Entergy Louisiana. A portion of the proceeds were applied in April 2021 to the refunding of $83.68 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana. The remainder of the proceeds were applied in June 2021 to the refunding of $115 million of outstanding pollution control revenue bonds previously issued on behalf of Entergy Louisiana.

(Entergy Mississippi)

In March 2021, Entergy Mississippi issued $200 million of 3.50% Series mortgage bonds due June 2051. Entergy Mississippi used the proceeds, together with other funds, to repay a portion of the debt outstanding under its three short-term revolving credit facilities with an aggregate commitment of $82.5 million and for general corporate purposes.

(Entergy Texas)

In May 2021, Entergy Texas redeemed $125 million of 2.55% Series mortgage bonds due June 2021.

(System Energy)

In June 2021, System Energy arranged for the issuance by the Mississippi Business Finance Corporation of $83.695 million of 2.375% revenue bonds (System Energy Resources, Inc. Project) Series 2021 due June 2044, which are evidenced by a series of System Energy first mortgage bonds. System Energy used the proceeds, together

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with other funds, to refund $83.695 million of outstanding revenue bonds.

Fair Value

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of June 30, 2021 were as follows:

			Book Value of Long-Term Debt						Fair Value of Long-Term Debt (a)
			(In Thousands)
Entergy			$24,497,290						$26,221,663
Entergy Arkansas			$4,043,714						$4,327,356
Entergy Louisiana			$9,836,133						$10,746,564
Entergy Mississippi			$1,981,674						$2,166,517
Entergy New Orleans			$636,870						$584,209
Entergy Texas			$2,323,879						$2,496,970
System Energy			$750,939						$771,477

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2020 were as follows:

			Book Value of Long-Term Debt						Fair Value of Long-Term Debt (a)
			(In Thousands)
Entergy			$22,369,776						$24,813,818
Entergy Arkansas			$3,967,507						$4,355,632
Entergy Louisiana			$9,027,451						$10,258,294
Entergy Mississippi			$1,780,577						$2,021,432
Entergy New Orleans			$642,233						$620,634
Entergy Texas			$2,493,708						$2,765,193
System Energy			$805,274						$840,540

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

NOTE 5.  STOCK-BASED COMPENSATION (Entergy Corporation)

Entergy grants stock and stock-based awards, which are described more fully in Note 12 to the financial statements in the Form 10-K.  Awards under Entergy’s plans generally vest over three years.

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Stock Options

Entergy granted options on 508,704 shares of its common stock under the 2019 Omnibus Incentive Plan during the first quarter 2021 with a fair value of $12.27 per option.  As of June 30, 2021, there were options on 2,844,446 shares of common stock outstanding with a weighted-average exercise price of $90.78.  The intrinsic value, which has no effect on net income, of the outstanding stock options is calculated by the positive difference between the weighted average exercise price of the stock options granted and Entergy Corporation’s common stock price as of June 30, 2021.  The aggregate intrinsic value of the stock options outstanding as of June 30, 2021 was $41.5 million.

The following table includes financial information for outstanding stock options for the three months ended June 30, 2021 and 2020:

			2021						2020
			(In Millions)
Compensation expense included in Entergy’s net income			$1.0						$1.0
Tax benefit recognized in Entergy’s net income			$0.2						$0.2
Compensation cost capitalized as part of fixed assets and materials and supplies			$0.4						$0.4

The following table includes financial information for outstanding stock options for the six months ended June 30, 2021 and 2020:

			2021						2020
			(In Millions)
Compensation expense included in Entergy’s net income			$2.0						$2.0
Tax benefit recognized in Entergy’s net income			$0.5						$0.5
Compensation cost capitalized as part of fixed assets and materials and supplies			$0.8						$0.8

Other Equity Awards

In January 2021 the Board approved and Entergy granted 392,382 restricted stock awards and 203,983 long-term incentive awards under the 2019 Omnibus Incentive Plan.  The restricted stock awards were made effective on January 28, 2021 and were valued at $95.87 per share, which was the closing price of Entergy’s common stock on that date.  Shares of restricted stock have the same dividend and voting rights as other common stock, are considered issued and outstanding shares of Entergy upon vesting, and are expensed ratably over the three-year vesting period. One-third of the restricted stock awards and accrued dividends will vest upon each anniversary of the grant date.  

In addition, long-term incentive awards were also granted in the form of performance units that represent the value of, and are settled with, one share of Entergy Corporation common stock at the end of the three-year performance period, plus dividends accrued during the performance period on the number of performance units earned. To emphasize the importance of strong cash generation for the long-term health of its business, Entergy Corporation is replacing the cumulative adjusted earnings per share metric with a credit measure – adjusted funds from operations/debt ratio for the 2021-2023 performance period. Performance will be measured based eighty percent on relative total shareholder return and twenty percent on the credit measure.  The performance units were granted on January 28, 2021 and eighty percent were valued at $110.74 per share based on various factors, primarily market conditions; and twenty percent were valued at $95.87 per share, the closing price of Entergy’s common stock on that date.  Performance units have the same dividend rights as shares of Entergy common stock and are considered issued and outstanding shares of Entergy upon vesting. Performance units are expensed ratably over the

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three-year vesting period and compensation cost for the portion of the award based on cumulative adjusted earnings per share will be adjusted based on the number of units that ultimately vest. See Note 12 to the financial statements in the Form 10-K for a description of the Long-Term Performance Unit Program.

The following table includes financial information for other outstanding equity awards for the three months ended June 30, 2021 and 2020:

			2021						2020
			(In Millions)
Compensation expense included in Entergy’s net income			$9.7						$9.6
Tax benefit recognized in Entergy’s net income			$2.5						$2.5
Compensation cost capitalized as part of fixed assets and materials and supplies			$4.0						$3.8

The following table includes financial information for other outstanding equity awards for the six months ended June 30, 2021 and 2020:

			2021						2020
			(In Millions)
Compensation expense included in Entergy’s net income			$20.5						$19.0
Tax benefit recognized in Entergy’s net income			$5.2						$4.9
Compensation cost capitalized as part of fixed assets and materials and supplies			$8.0						$7.2

NOTE 6.  RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Components of Qualified Net Pension Cost    

Entergy’s qualified pension cost, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components:

			2021						2020
			(In Thousands)
Service cost - benefits earned during the period			$42,951						$40,379
Interest cost on projected benefit obligation			47,382						60,799
Expected return on assets			(106,039)						(103,565)
Amortization of net loss			92,799						87,259
Settlement charges			111,549						—
Net pension costs			$188,642						$84,872

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Notes to Financial Statements

Entergy’s qualified pension cost, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components:

			2021						2020
			(In Thousands)
Service cost - benefits earned during the period			$88,191						$80,758
Interest cost on projected benefit obligation			93,480						121,598
Expected return on assets			(211,753)						(207,130)
Amortization of net loss			197,190						174,518
Settlement charges			111,549						—
Net pension costs			$278,657						$169,744

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components:

2021						Entergy Arkansas						Entergy Louisiana						Entergy  Mississippi						Entergy New Orleans						Entergy Texas						System Energy
						(In Thousands)
Service cost - benefits earned during the period						$7,255						$9,759						$2,304						$774						$1,757						$2,253
Interest cost on projected benefit obligation						8,752						9,864						2,571						1,079						2,052						2,236
Expected return on assets						(19,640)						(22,516)						(5,600)						(2,641)						(5,272)						(4,804)
Amortization of net loss						18,250						17,890						5,309						2,069						3,415						4,933
Settlement charges						24,386						34,992						7,762						3,585						6,626						4,638
Net pension cost						$39,003						$49,989						$12,346						$4,866						$8,578						$9,256

2020						Entergy Arkansas						Entergy Louisiana						Entergy  Mississippi						Entergy New Orleans						Entergy Texas						System Energy
						(In Thousands)
Service cost - benefits earned during the period						$6,566						$8,794						$2,023						$663						$1,546						$1,965
Interest cost on projected benefit obligation						11,433						12,841						3,340						1,456						2,782						2,814
Expected return on assets						(19,622)						(22,402)						(5,757)						(2,627)						(5,486)						(4,663)
Amortization of net loss						16,897						16,627						4,748						2,005						3,265						4,279
Net pension cost						$15,274						$15,860						$4,354						$1,497						$2,107						$4,395

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Notes to Financial Statements

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components:

2021						Entergy Arkansas						Entergy Louisiana						Entergy  Mississippi						Entergy New Orleans						Entergy Texas						System Energy
						(In Thousands)
Service cost - benefits earned during the period						$14,674						$19,803						$4,668						$1,569						$3,557						$4,566
Interest cost on projected benefit obligation						17,092						19,425						5,034						2,108						4,002						4,378
Expected return on assets						(39,311)						(45,055)						(11,186)						(5,263)						(10,510)						(9,583)
Amortization of net loss						37,552						37,093						10,976						4,340						7,126						10,258
Settlement charges						24,386						34,992						7,762						3,585						6,626						4,638
Net pension cost						$54,393						$66,258						$17,254						$6,339						$10,801						$14,257

2020						Entergy Arkansas						Entergy Louisiana						Entergy  Mississippi						Entergy New Orleans						Entergy Texas						System Energy
						(In Thousands)
Service cost - benefits earned during the period						$13,132						$17,588						$4,046						$1,326						$3,092						$3,930
Interest cost on projected benefit obligation						22,866						25,682						6,680						2,912						5,564						5,628
Expected return on assets						(39,244)						(44,804)						(11,514)						(5,254)						(10,972)						(9,326)
Amortization of net loss						33,794						33,254						9,496						4,010						6,530						8,558
Net pension cost						$30,548						$31,720						$8,708						$2,994						$4,214						$8,790

Non-Qualified Net Pension Cost

Entergy recognized $4.6 million and $4.5 million in pension cost for its non-qualified pension plans in the second quarters of 2021 and 2020, respectively. Entergy recognized $9.2 million and $9.1 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2021 and 2020.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the second quarters of 2021 and 2020:

			Entergy Arkansas						Entergy Louisiana						Entergy Mississippi						Entergy New Orleans						Entergy Texas
			(In Thousands)
2021			$90						$44						$96						$8						$115
2020			$83						$37						$90						$8						$117

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Notes to Financial Statements

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the six months ended June 30, 2021 and 2020:

			Entergy Arkansas						Entergy Louisiana						Entergy Mississippi						Entergy New Orleans						Entergy Texas
			(In Thousands)
2021			$180						$88						$192						$16						$230
2020			$166						$74						$180						$16						$234

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit income, including amounts capitalized, for the second quarters of 2021 and 2020, included the following components:

			2021						2020
			(In Thousands)
Service cost - benefits earned during the period			$6,645						$6,231
Interest cost on accumulated postretirement benefit obligation (APBO)			5,320						6,888
Expected return on assets			(10,805)						(10,182)
Amortization of prior service credit			(8,267)						(8,985)
Amortization of net loss			713						1,005
Net other postretirement benefit income			($6,394)						($5,043)

Entergy’s other postretirement benefit cost income, including amounts capitalized, for the six months ended June 30, 2021 and 2020, included the following components:

			2021						2020
			(In Thousands)
Service cost - benefits earned during the period			$13,290						$12,032
Interest cost on accumulated postretirement benefit obligation (APBO)			10,640						14,820
Expected return on assets			(21,610)						(20,510)
Amortization of prior service credit			(16,534)						(14,907)
Amortization of net loss			1,426						1,473
Net other postretirement benefit income			($12,788)						($7,092)

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Notes to Financial Statements

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the second quarters of 2021 and 2020, included the following components:

2021						Entergy Arkansas						Entergy Louisiana						Entergy Mississippi						Entergy New Orleans						Entergy Texas						System Energy
						(In Thousands)
Service cost - benefits earned during the period						$1,034						$1,544						$362						$109						$346						$335
Interest cost on APBO						932						1,130						278						130						317						220
Expected return on assets						(4,505)						—						(1,384)						(1,438)						(2,548)						(789)
Amortization of prior service credit						(280)						(1,230)						(444)						(229)						(936)						(109)
Amortization of net (gain) loss						49						(91)						19						(178)						100						15
Net other postretirement benefit cost (income)						($2,770)						$1,353						($1,169)						($1,606)						($2,721)						($328)

2020						Entergy Arkansas						Entergy Louisiana						Entergy Mississippi						Entergy New Orleans						Entergy Texas						System Energy
						(In Thousands)
Service cost - benefits earned during the period						$933						$1,524						$372						$114						$306						$321
Interest cost on APBO						1,164						1,497						372						186						477						276
Expected return on assets						(4,260)						—						(1,287)						(1,344)						(2,403)						(735)
Amortization of prior service credit						(396)						(1,695)						(444)						(228)						(939)						(282)
Amortization of net (gain) loss						162						(81)						48						9						231						33
Net other postretirement benefit cost (income)						($2,397)						$1,245						($939)						($1,263)						($2,328)						($387)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the six months ended June 30, 2021 and 2020, included the following components:

2021						Entergy Arkansas						Entergy Louisiana						Entergy Mississippi						Entergy New Orleans						Entergy Texas						System Energy
						(In Thousands)
Service cost - benefits earned during the period						$2,068						$3,088						$724						$218						$692						$670
Interest cost on APBO						1,864						2,260						556						260						634						440
Expected return on assets						(9,010)						—						(2,768)						(2,876)						(5,096)						(1,578)
Amortization of prior service credit						(560)						(2,460)						(888)						(458)						(1,872)						(218)
Amortization of net (gain) loss						98						(182)						38						(356)						200						30
Net other postretirement benefit cost (income)						($5,540)						$2,706						($2,338)						($3,212)						($5,442)						($656)

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Notes to Financial Statements

2020						Entergy Arkansas						Entergy Louisiana						Entergy Mississippi						Entergy New Orleans						Entergy Texas						System Energy
						(In Thousands)
Service cost - benefits earned during the period						$1,761						$2,947						$723						$219						$609						$615
Interest cost on APBO						2,381						3,220						794						413						1,059						583
Expected return on assets						(8,586)						—						(2,594)						(2,699)						(4,838)						(1,483)
Amortization of prior service credit						(1,057)						(2,784)						(765)						(304)						(1,489)						(501)
Amortization of net (gain) loss						217						(280)						77						(29)						443						53
Net other postretirement benefit cost (income)						($5,284)						$3,103						($1,765)						($2,400)						($4,216)						($733)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2021 and 2020:

2021						Qualified Pension Costs						Other Postretirement Costs						Non-Qualified Pension Costs						Total
						(In Thousands)
Entergy
Amortization of prior service (cost) credit						$—						$5,288						($40)						$5,248
Amortization of net loss						(26,443)						(496)						(595)						(27,534)
Settlement loss						(6,043)						—						—						(6,043)
						($32,486)						$4,792						($635)						($28,329)
Entergy Louisiana
Amortization of prior service credit						$—						$1,230						$—						$1,230
Amortization of net gain (loss)						(716)						91						(1)						(626)
Settlement loss						(1,400)						—						—						($1,400)
						($2,116)						$1,321						($1)						($796)

2020						Qualified Pension Costs						Other Postretirement Costs						Non-Qualified Pension Costs						Total
						(In Thousands)
Entergy
Amortization of prior service (cost) credit						$—						$5,739						($57)						$5,682
Amortization of net loss						(26,461)						(327)						(831)						(27,619)
						($26,461)						$5,412						($888)						($21,937)
Entergy Louisiana
Amortization of prior service credit						$—						$1,698						$—						$1,698
Amortization of net gain (loss)						(499)						81						(1)						(419)
						($499)						$1,779						($1)						$1,279

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Notes to Financial Statements

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2021 and 2020:

2021						Qualified Pension Costs						Other Postretirement Costs						Non-Qualified Pension Costs						Total
						(In Thousands)
Entergy
Amortization of prior service (cost) credit						$—						$10,576						($80)						$10,496
Amortization of net loss						(59,883)						(990)						(1,190)						(62,063)
Settlement loss						(6,043)						—						—						(6,043)
						($65,926)						$9,586						($1,270)						($57,610)
Entergy Louisiana
Amortization of prior service credit						$—						$2,460						$—						$2,460
Amortization of net gain (loss)						(1,484)						182						(3)						(1,305)
Settlement loss						(1,400)						—						—						(1,400)
						($2,884)						$2,642						($3)						($245)

2020						Qualified Pension Costs						Other Postretirement Costs						Non-Qualified Pension Costs						Total
						(In Thousands)
Entergy
Amortization of prior service (cost) credit						$—						$9,516						($115)						$9,401
Amortization of net loss						(52,923)						(352)						(1,662)						(54,937)
						($52,923)						$9,164						($1,777)						($45,536)
Entergy Louisiana
Amortization of prior service credit						$—						$2,787						$—						$2,787
Amortization of net gain (loss)						(998)						280						(2)						(720)
						($998)						$3,067						($2)						$2,067

Accounting for Pension and Other Postretirement Benefits

In accordance with ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

Other Postretirement Benefits

In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in a new Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the new Entergy retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. In accordance with accounting standards, the effects of this change were reflected in the March 31, 2020 other postretirement obligation.

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Notes to Financial Statements

Qualified Pension Settlement Cost

In the second quarter of 2021, year-to-date lump sum benefit payments from the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining Employees exceeded the sum of the Plans’ 2021 service and interest cost, resulting in a settlement cost of $111.5 million. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plans’ pension liability. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy participate in one or both of the Entergy Corporation Retirement Plan for Bargaining Employees and the Entergy Corporation Retirement Plan for Non-Bargaining employees and incurred settlement costs of $24.4 million, $35 million, $7.8 million, $3.6 million, $6.6 million, and $4.6 million, respectively. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans received regulatory approval to defer the expense portion of the settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred.

Entergy Texas Reserve

In September 2020, Entergy Texas elected to establish a reserve, in accordance with PUCT regulations, for the difference between the amount recorded for pension and other postretirement benefits expense under generally accepted accounting principles during 2019, the first year that rates from Entergy Texas’s last general rate proceeding were in effect, and the annual amount of actuarially determined pension and other postretirement benefits chargeable to Entergy Texas’s expense. The reserve amount will be evaluated in the next scheduled PUCT rate case and a reasonable amortization period will be determined by the PUCT at that time. At June 30, 2021, the balance in this reserve was approximately $10.1 million.

Employer Contributions

Based on current assumptions, Entergy expects to contribute $356 million to its qualified pension plans in 2021.  As of June 30, 2021, Entergy had contributed $220.1 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2021:

			Entergy Arkansas						Entergy Louisiana						Entergy Mississippi						Entergy New Orleans						Entergy Texas						System Energy
			(In Thousands)
Expected 2021 pension contributions			$66,649						$59,882						$13,715						$5,395						$6,955						$18,663
Pension contributions made through June 2021			$36,457						$39,400						$7,771						$3,551						$4,275						$10,671
Remaining estimated pension contributions to be made in 2021			$30,192						$20,482						$5,944						$1,844						$2,680						$7,992

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Notes to Financial Statements

NOTE 7.  BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy’s reportable segments as of June 30, 2021 were 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, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating 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.

Entergy’s segment financial information for the second quarters of 2021 and 2020 was as follows:

						Utility						Entergy Wholesale Commodities						All Other						Eliminations						Entergy
						(In Thousands)
2021
Operating revenues						$2,673,385						$148,656						$31						($2)						$2,822,070
Income taxes						$71,360						($71,696)						($18,080)						$—						($18,416)
Consolidated net income (loss)						$329,936						($274,648)						($24,784)						($31,898)						($1,394)
2020
Operating revenues						$2,213,061						$199,709						$18						$—						$2,412,788
Income taxes						$73,710						$24,467						($9,062)						$—						$89,115
Consolidated net income (loss)						$348,902						$85,178						($37,069)						($31,898)						$365,113

Entergy’s segment financial information for the six months ended June 30, 2021 and 2020 was as follows:

						Utility						Entergy Wholesale Commodities						All Other						Eliminations						Consolidated
						(In Thousands)
2021
Operating revenues						$5,270,000						$396,874						$54						($21)						$5,666,907
Income taxes						$131,094						($56,135)						($27,433)						$—						$47,526
Consolidated net income (loss)						$690,535						($236,525)						($52,464)						($63,796)						$337,750
Total assets as of June 30, 2021						$56,240,370						$1,209,209						$496,043						($1,996,339)						$55,949,283
2020
Operating revenues						$4,307,690						$532,258						$29						($10)						$4,839,967
Income taxes						$20,761						($6,073)						$3,233						$—						$17,921
Consolidated net income (loss)						$672,751						($25,251)						($95,298)						($63,796)						$488,406
Total assets as of December 31, 2020						$55,940,153						$3,800,378						$552,632						($2,053,951)						$58,239,212

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations were primarily intersegment activity. Almost all of Entergy’s goodwill was related to the Utility segment.

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Notes to Financial Statements

As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of its plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions.

Total restructuring charges for the second quarters of 2021 and 2020 were comprised of the following:

			2021																		2020
			Employee retention and severance expenses and other benefits-related costs						Contracted economic development costs						Total						Employee retention and severance expenses and other benefits-related costs						Contracted economic development costs						Total
			(In Millions)
Balance as of April 1,			$157						$14						$171						$150						$14						$164
Restructuring costs accrued			(6)						1						(5)						17						—						17
Cash paid out			118						15						133						14						—						14
Balance as of June 30,			$33						$—						$33						$153						$14						$167

In addition, Entergy Wholesale Commodities incurred $342 million in the second quarter 2021 and $7 million in the second quarter 2020 of impairment and other related charges associated with these strategic decisions and transactions.

Total restructuring charges for the six months ended June 30, 2021 and 2020 were comprised of the following:

			2021																		2020
			Employee retention and severance expenses and other benefits-related costs						Contracted economic development costs						Total						Employee retention and severance expenses and other benefits-related costs						Contracted economic development costs						Total
			(In Millions)
Balance as of January 1,			$145						$14						$159						$129						$14						$143
Restructuring costs accrued			7						1						8						38						—						38
Cash paid out			119						15						134						14						—						14
Balance as of June 30,			$33						$—						$33						$153						$14						$167

In addition, Entergy Wholesale Commodities incurred $345 million in the six months ended June 30, 2021 and $12 million in the six months ended June 30, 2020 of impairment and other related charges associated with these strategic decisions and transactions.

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Notes to Financial Statements

Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $10 million in 2021, of which $7 million has been incurred as of June 30, 2021, and a total of approximately $5 million in 2022.

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 8.  RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Market Risk

In the normal course of business, Entergy is exposed to a number of market 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 commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk.

The Utility 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 regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities entered into forward contracts with its customers and also sold energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities used a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price fell, the combination of financial contracts was expected to settle in gains that offset lower revenue from generation, which resulted in a more predictable cash flow.

Consistent with management’s strategy to shut down and sell all plants in the Entergy Wholesale Commodities merchant fleet, the Entergy Wholesale Commodities portfolio of derivative instruments expired in April 2021, which was the settlement date for the last financial derivative contracts in the Entergy Wholesale Commodities portfolio.

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.  Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace.  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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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Derivatives

Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale 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 swaps and options and interest rate swaps.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments.

Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for Entergy Wholesale Commodities generation. Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 98% for the remainder of 2021, all of which is sold under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2021 is 3.4 TWh.

Entergy used standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitated the netting of cash flows associated with a single counterparty and may have included collateral requirements. Cash, letters of credit, and parental/affiliate guarantees were obtained as security from counterparties in order to mitigate credit risk. The collateral agreements required a counterparty to post cash or letters of credit in the event an exposure exceeded an established threshold. The threshold represented an unsecured credit limit, which may have been supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allowed for termination and liquidation of all positions in the event of a failure or inability to post collateral.

Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.  As of June 30, 2021, there were no outstanding derivative contracts held by Entergy Wholesale Commodities. As of December 31, 2020, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $5 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties and $39 million in letters of credit were required to be posted by it counterparties to the Entergy subsidiary.   

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy had executed natural gas swaps and options as of June 30, 2021 was 2.75 years for Entergy Louisiana and the maximum length of time over which Entergy had executed natural gas swaps as of June 30, 2021 was 9 months, each, for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of June 30, 2021 was 33,969,600 MMBtu for Entergy, including 20,100,000 MMBtu for Entergy Louisiana, 13,569,000 MMBtu for Entergy Mississippi, and 300,600 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

During the second quarter 2021, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2021 through May 31, 2022. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of June 30, 2021 was 126,149 GWh for Entergy, including 25,505 GWh for Entergy Arkansas, 58,280 GWh for Entergy Louisiana, 14,634 GWh for Entergy Mississippi, 5,842 GWh for Entergy New Orleans, and 21,399 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. As of June 30, 2021, $5 million in cash collateral was required to be posted by Entergy Wholesale Commodities to MISO. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of December 31, 2020. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of June 30, 2021 and for Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2020.

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of June 30, 2021 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument

Balance Sheet Location

Gross Fair Value (a)

Offsetting Position (b)

Net Fair Value (c) (d)

Business

(In Millions)

Derivatives not designated as hedging instruments

Assets:

Natural gas swaps and options

Prepayments and other (current portion)

$15

$—

$15

Utility

Financial transmission rights

Prepayments and other

$16

($1)

$15

Utility and Entergy Wholesale Commodities

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Notes to Financial Statements

The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2020 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument

Balance Sheet Location

Gross Fair Value (a)

Offsetting Position (b)

Net Fair Value (c) (d)

Business

(In Millions)

Derivatives designated as hedging instruments

Assets:

Electricity swaps and options

Prepayments and other (current portion)

$39

($1)

$38

Entergy Wholesale Commodities

Liabilities:

Electricity swaps and options

Other current liabilities (current portion)

$1

($1)

$—

Entergy Wholesale Commodities

Derivatives not designated as hedging instruments

Assets:

Natural gas swaps and options

Prepayments and other (current portion)

$1

$—

$1

Utility

Natural gas swaps and options

Other deferred debits and other assets (non-current portion)

$1

$—

$1

Utility

Financial transmission rights

Prepayments and other

$9

$—

$9

Utility and Entergy Wholesale Commodities

Liabilities:

Natural gas swaps and options

Other current liabilities (current portion)

$6

$—

$6

Utility

Natural gas swaps and options

Other non-current liabilities (non-current portion)

$1

$—

$1

Utility

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet

(d)Excludes cash collateral in the amount of $5 million posted as of June 30, 2021 and $5 million posted as of December 31, 2020. Also excludes letters of credit in the amount of $6 million posted as of June 30, 2021 and $1 million posted and $39 million held as of December 31, 2020.

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Notes to Financial Statements

The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended June 30, 2021 and 2020 were as follows:

Instrument

Amount of gain (loss) recognized in other comprehensive income

Income Statement location

Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)

(In Millions)

(In Millions)

2021

Electricity swaps and options

$—

Competitive businesses operating revenues

$—

2020

Electricity swaps and options

($7)

Competitive businesses operating revenues

$25

(a)Before taxes of $5 million for the three months ended June 30, 2020

The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows:

Instrument

Amount of gain (loss) recognized in other comprehensive income

Income Statement location

Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)

(In Millions)

(In Millions)

2021

Electricity swaps and options

$2

Competitive businesses operating revenues

$40

2020

Electricity swaps and options

$60

Competitive businesses operating revenues

$120

(a)Before taxes of $8 million and $25 million for the six months ended June 30, 2021 and 2020, respectively

Based on market prices as of June 30, 2021, there were no unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales.

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 other comprehensive income prior to de-designation continue to be deferred in other comprehensive income 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.

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Notes to Financial Statements

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended June 30, 2021 and 2020 were as follows:

Instrument

Income Statement location

Amount of gain (loss) recorded in the income statement

(In Millions)

2021

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

(a)

$18

Financial transmission rights

Purchased power expense

(b)

$16

Electricity swaps and options (c)

Competitive business operating revenues

$—

2020

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

(a)

($3)

Financial transmission rights

Purchased power expense

(b)

$15

Electricity swaps and options (c)

Competitive business operating revenues

($2)

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2021 and 2020 were as follows:

Instrument

Income Statement location

Amount of gain (loss) recorded in the income statement

(In Millions)

2021

Natural gas swaps and options

Fuel, fuel-related expenses, and gas purchased for resale

(a)

$25

Financial transmission rights

Purchased power expense

(b)

$144

Electricity swaps and options (c)

Competitive business operating revenues

($2)

2020

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

(a)

($9)

Financial transmission rights

Purchased power expense

(b)

$28

Electricity swaps and options (c)

Competitive business operating revenues

($2)

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Notes to Financial Statements

(a)Due to regulatory treatment, the natural gas swaps and options 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 and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

(c)There were no gains (losses) recognized in accumulated other comprehensive income from electricity swaps and options.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of June 30, 2021 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument						Balance Sheet Location						Gross Fair Value (a)						Offsetting Position (b)						Net Fair Value (c) (d)						Registrant
												(In Millions)
Assets:
Natural gas swaps and options						Prepayments and other						$5.0						$—						$5.0						Entergy Louisiana
Natural gas swaps and options						Other deferred debits and other assets (non-current portion)						$0.4						$—						$0.4						Entergy Louisiana
Natural gas swaps						Prepayments and other						$9.6						$—						$9.6						Entergy Mississippi
Natural gas swaps						Prepayments and other						$0.1						$—						$0.1						Entergy New Orleans
Financial transmission rights						Prepayments and other						$4.1						($0.3)						$3.8						Entergy Arkansas
Financial transmission rights						Prepayments and other						$4.9						($0.1)						$4.8						Entergy Louisiana
Financial transmission rights						Prepayments and other						$2.0						$—						$2.0						Entergy Mississippi
Financial transmission rights						Prepayments and other						$0.6						$—						$0.6						Entergy New Orleans
Financial transmission rights						Prepayments and other						$3.8						$—						$3.8						Entergy Texas

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Notes to Financial Statements

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2020 were as follows:

Instrument						Balance Sheet Location						Gross Fair Value (a)						Offsetting Position (b)						Net Fair Value (c) (d)						Registrant
												(In Millions)
Assets:
Natural gas swaps and options						Prepayments and other						$0.8						$—						$0.8						Entergy Louisiana
Natural gas swaps and options						Other deferred debits and other assets						$0.5						$—						$0.5						Entergy Louisiana
Financial transmission rights						Prepayments and other						$2.9						($0.2)						$2.7						Entergy Arkansas
Financial transmission rights						Prepayments and other						$4.3						($0.1)						$4.2						Entergy Louisiana
Financial transmission rights						Prepayments and other						$0.6						$—						$0.6						Entergy Mississippi
Financial transmission rights						Prepayments and other						$0.2						($0.1)						$0.1						Entergy New Orleans
Financial transmission rights						Prepayments and other						$1.6						$—						$1.6						Entergy Texas
Liabilities:
Natural gas swaps and options						Other current liabilities						$0.3						$—						$0.3						Entergy Louisiana
Natural gas swaps and options						Other non-current liabilities						$1.3						$—						$1.3						Entergy Louisiana
Natural gas swaps						Other current liabilities						$5.0						$—						$5.0						Entergy Mississippi
Natural gas swaps						Other current liabilities						$0.3						$—						$0.3						Entergy New Orleans

(a)Represents the gross amounts of recognized assets/liabilities

(b)Represents the netting of fair value balances with the same counterparty

(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

(d)As of June 30, 2021, letters of credit posted with MISO covered financial transmission rights exposure of $1.5 million for Entergy Arkansas, $0.7 million for Entergy Louisiana, $0.9 million for Entergy Mississippi, $0.3 million for Entergy New Orleans, and $2.3 million for Entergy Texas. As of December 31, 2020, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Louisiana, $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $0.5 million for Entergy Texas.

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Notes to Financial Statements

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended June 30, 2021 and 2020 were as follows:

Instrument

Income Statement Location

Amount of gain (loss) recorded in the income statement

Registrant

(In Millions)

2021

Natural gas swaps and options

Fuel, fuel-related expenses, and gas purchased for resale

$4.9

(a)

Entergy Louisiana

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

$13.2

(a)

Entergy Mississippi

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

$0.1

(a)

Entergy New Orleans

Financial transmission rights

Purchased power expense

$3.4

(b)

Entergy Arkansas

Financial transmission rights

Purchased power expense

$5.9

(b)

Entergy Louisiana

Financial transmission rights

Purchased power expense

$0.7

(b)

Entergy Mississippi

Financial transmission rights

Purchased power expense

$0.8

(b)

Entergy New Orleans

Financial transmission rights

Purchased power expense

$4.8

(b)

Entergy Texas

2020

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

($2.5)

(a)

Entergy Mississippi

Financial transmission rights

Purchased power expense

$4.8

(b)

Entergy Arkansas

Financial transmission rights

Purchased power expense

$5.4

(b)

Entergy Louisiana

Financial transmission rights

Purchased power expense

($0.4)

(b)

Entergy Mississippi

Financial transmission rights

Purchased power expense

$0.2

(b)

Entergy New Orleans

Financial transmission rights

Purchased power expense

$5.3

(b)

Entergy Texas

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Notes to Financial Statements

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the six months ended June 30, 2021 and 2020 were as follows:

Instrument

Income Statement Location

Amount of gain (loss) recorded in the income statement

Registrant

(In Millions)

2021

Natural gas swaps and options

Fuel, fuel-related expenses, and gas purchased for resale

$6.7

(a)

Entergy Louisiana

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

$18.3

(a)

Entergy Mississippi

Financial transmission rights

Purchased power expense

$29.5

(b)

Entergy Arkansas

Financial transmission rights

Purchased power expense

$18.2

(b)

Entergy Louisiana

Financial transmission rights

Purchased power expense

$7.9

(b)

Entergy Mississippi

Financial transmission rights

Purchased power expense

$2.0

(b)

Entergy New Orleans

Financial transmission rights

Purchased power expense

$82.7

(b)

Entergy Texas

2020

Natural gas swaps and options

Fuel, fuel-related expenses, and gas purchased for resale

($1.3)

(a)

Entergy Louisiana

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

($7.7)

(a)

Entergy Mississippi

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

($0.4)

(a)

Entergy New Orleans

Financial transmission rights

Purchased power expense

$9.4

(b)

Entergy Arkansas

Financial transmission rights

Purchased power expense

$10.7

(b)

Entergy Louisiana

Financial transmission rights

Purchased power expense

($0.5)

(b)

Entergy Mississippi

Financial transmission rights

Purchased power expense

$0.6

(b)

Entergy New Orleans

Financial transmission rights

Purchased power expense

$7.6

(b)

Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps and options 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 and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, 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 those instruments held by

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Notes to Financial Statements

the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. 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 (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•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.

Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs.

•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 financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants.

The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight and the Entergy Wholesale Commodities Accounting group.  The primary related functions of the Office of

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Corporate Risk Oversight include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system.  The Office of Corporate Risk Oversight is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The amounts reflected as the fair value of electricity swaps 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 to 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 the 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.  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.  For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms.

The amounts reflected as the fair values of electricity options are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes.  Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate.  As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value.  

On a daily basis, the Office of Corporate Risk Oversight calculates the mark-to-market for electricity swaps and options.  The Office of Corporate Risk Oversight also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions.  Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities.  Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis.  The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects are calculated for this analysis.  This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight.  The values are calculated internally and verified against the data published by MISO. Entergy’s Entergy Wholesale Commodities Accounting group review these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer.  The Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

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Notes to Financial Statements

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that were accounted for at fair value on a recurring basis as of June 30, 2021 and December 31, 2020.  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.

2021						Level 1						Level 2						Level 3						Total
						(In Millions)
Assets:
Temporary cash investments						$530						$—						$—						$530
Decommissioning trust funds (a):
Equity securities						53						—						—						53
Debt securities (b)						686						1,352						—						2,038
Common trusts (c)																								3,148
Securitization recovery trust account						33						—						—						33
Escrow accounts						88						—						—						88
Gas hedge contracts						15						—						—						15
Financial transmission rights						—						—						15						15
						$1,405						$1,352						$15						$5,920

2020						Level 1						Level 2						Level 3						Total
						(In Millions)
Assets:
Temporary cash investments						$1,630						$—						$—						$1,630
Decommissioning trust funds (a):
Equity securities						1,533						—						—						1,533
Debt securities (b)						919						1,698						—						2,617
Common trusts (c)																								3,103
Power contracts						—						—						38						38
Securitization recovery trust account						42						—						—						42
Escrow accounts						148						—						—						148
Gas hedge contracts						1						1						—						2
Financial transmission rights						—						—						9						9
						$4,273						$1,699						$47						$9,122
Liabilities:
Gas hedge contracts						$6						$1						$—						$7

(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 9 to the financial statements herein for additional information on the investment portfolios.

(b)The decommissioning trust funds fair values presented herein do not include the recognition pursuant to ASU 2016-13 of a credit loss valuation allowance of $0.2 million as of June 30, 2021 and $0.1 million as of December 31, 2020 on debt securities. See Note 9 to the financial statements herein for additional information on the allowance for expected credit losses.

(c)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

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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 three months ended June 30, 2021 and 2020:

			2021												2020
			Power Contracts						Financial transmission rights						Power Contracts						Financial transmission rights
			(In Millions)
Balance as of April 1,			$—						$4						$85						$4
Total gains (losses) for the period (a)
Included in earnings			—						—						16						—
Included in other comprehensive income			—						—						(7)						—
Included as a regulatory liability/asset			—						15						—						10
Issuances of financial transmission rights			—						12						—						23
Settlements			—						(16)						(45)						(15)
Balance as of June 30,			$—						$15						$49						$22

(a)Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period was $3 million for the three months ended June 30, 2020.

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 six months ended June 30, 2021 and 2020:

			2021												2020
			Power Contracts						Financial transmission rights						Power Contracts						Financial transmission rights
			(In Millions)
Balance as of January 1,			$38						$9						$118						$10
Total gains (losses) for the period (a)
Included in earnings			(2)						3						(2)						—
Included in other comprehensive income			2						—						60						—
Included as a regulatory liability/asset			—						135						—						17
Issuances of financial transmission rights			—						12						—						23
Settlements			(38)						(144)						(127)						(28)
Balance as of June 30,			$—						$15						$49						$22

(a)Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period was $4 million for the six months ended June 30, 2020.

The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.

The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs:

Significant Unobservable Input

Transaction Type

Position

Change to Input

Effect on Fair Value

Unit contingent discount

Electricity swaps

Sell

Increase (Decrease)

Decrease (Increase)

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The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that were accounted for at fair value on a recurring basis as of June 30, 2021 and December 31, 2020.  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

2021						Level 1						Level 2						Level 3						Total
						(In Millions)
Assets:
Temporary cash investments						$16.2						$—						$—						$16.2
Decommissioning trust funds (a):
Equity securities						12.7						—						—						12.7
Debt securities						99.2						373.3						—						472.5
Common trusts (b)																								891.5
Financial transmission rights						—						—						3.8						3.8
						$128.1						$373.3						$3.8						$1,396.7

2020						Level 1						Level 2						Level 3						Total
						(In Millions)
Assets:
Temporary cash investments						$168.0						$—						$—						$168.0
Decommissioning trust funds (a):
Equity securities						1.3						—						—						1.3
Debt securities						98.2						349.7						—						447.9
Common trusts (b)																								824.7
Financial transmission rights						—						—						2.7						2.7
						$267.5						$349.7						$2.7						$1,444.6

Entergy Louisiana

2021						Level 1						Level 2						Level 3						Total
						(In Millions)
Assets:
Temporary cash investments						$206.6						$—						$—						$206.6
Decommissioning trust funds (a):
Equity securities						19.6						—						—						19.6
Debt securities						213.2						484.3						—						697.5
Common trusts (b)																								1,268.4
Securitization recovery trust account						3.7						—						—						3.7
Gas hedge contracts						5.0						0.4						—						5.4
Financial transmission rights						—						—						4.8						4.8
						$448.1						$484.7						$4.8						$2,206.0

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2020						Level 1						Level 2						Level 3						Total
						(In Millions)
Assets:
Temporary cash investments						$726.7						$—						$—						$726.7
Decommissioning trust funds (a):
Equity securities						8.7						—						—						8.7
Debt securities						172.4						459.8						—						632.2
Common trusts (b)																								1,153.1
Securitization recovery trust account						2.7						—						—						2.7
Gas hedge contracts						0.8						0.5						—						1.3
Financial transmission rights						—						—						4.2						4.2
						$911.3						$460.3						$4.2						$2,528.9
Liabilities:
Gas hedge contracts						$0.3						$1.3						$—						$1.6

Entergy Mississippi

2021						Level 1						Level 2						Level 3						Total
						(In Millions)
Assets:
Escrow accounts						$48.9						$—						$—						$48.9
Gas hedge contracts						9.6						—						—						9.6
Financial transmission rights						—						—						2.0						2.0
						$58.5						$—						$2.0						$60.5

2020						Level 1						Level 2						Level 3						Total
						(In Millions)
Assets:
Escrow accounts						$64.6						$—						$—						$64.6
Financial transmission rights						—						—						0.6						0.6
						$64.6						$—						$0.6						$65.2
Liabilities:
Gas hedge contracts						$5.0						$—						$—						$5.0

Entergy New Orleans

2021						Level 1						Level 2						Level 3						Total
						(In Millions)
Assets:
Securitization recovery trust account						$2.7						$—						$—						$2.7
Escrow accounts						38.8						—						—						38.8
Gas hedge contracts						0.1						—						—						0.1
Financial transmission rights						—						—						0.6						0.6
						$41.6						$—						$0.6						$42.2

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2020						Level 1						Level 2						Level 3						Total
						(In Millions)
Assets:
Securitization recovery trust account						$3.4						$—						$—						$3.4
Escrow accounts						83.0						—						—						83.0
Financial transmission rights						—						—						0.1						0.1
						$86.4						$—						$0.1						$86.5
Liabilities:
Gas hedge contracts						$0.3						$—						$—						$0.3

Entergy Texas

2021						Level 1						Level 2						Level 3						Total
						(In Millions)
Assets:
Securitization recovery trust account						$26.3						$—						$—						$26.3
Financial transmission rights						—						—						3.8						3.8
						$26.3						$—						$3.8						$30.1

2020						Level 1						Level 2						Level 3						Total
						(In Millions)
Assets:
Temporary cash investments						$248.6						$—						$—						$248.6
Securitization recovery trust account						36.2						—						—						36.2
Financial transmission rights						—						—						1.6						1.6
						$284.8						$—						$1.6						$286.4

System Energy

2021						Level 1						Level 2						Level 3						Total
						(In Millions)
Assets:
Temporary cash investments						$119.1						$—						$—						$119.1
Decommissioning trust funds (a):
Equity securities						6.0						—						—						6.0
Debt Securities						207.3						260.5						—						467.8
Common trusts (b)																								838.7
						$332.4						$260.5						$—						$1,431.6

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2020						Level 1						Level 2						Level 3						Total
						(In Millions)
Assets:
Temporary cash investments						$216.4						$—						$—						$216.4
Decommissioning trust funds (a):
Equity securities						3.8						—						—						3.8
Debt securities						177.3						250.4						—						427.7
Common trusts (b)																								784.4
						$397.5						$250.4						$—						$1,432.3

(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 9 to the financial statements herein for additional information on the investment portfolios.

(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

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 three months ended June 30, 2021.

			Entergy Arkansas						Entergy Louisiana						Entergy Mississippi						Entergy New Orleans						Entergy Texas
			(In Millions)
Balance as of April 1,			$1.4						$1.2						$0.3						$0.1						$0.5
Issuances of financial transmission rights			2.8						4.1						1.7						0.4						2.7
Gains (losses) included as a regulatory liability/asset			3.0						5.4						0.8						0.9						5.4
Settlements			(3.4)						(5.9)						(0.7)						(0.8)						(4.8)
Balance as of June 30,			$3.8						$4.8						$2.1						$0.6						$3.8

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 three months ended June 30, 2020.

			Entergy Arkansas						Entergy Louisiana						Entergy Mississippi						Entergy New Orleans						Entergy Texas
			(In Millions)
Balance as of April 1,			$1.1						$1.9						$0.3						$—						$0.3
Issuances of financial transmission rights			6.5						13.2						1.4						(0.1)						2.4
Gains (losses) included as a regulatory liability/asset			3.3						2.8						(1.0)						0.1						5.2
Settlements			(4.8)						(5.4)						0.4						(0.2)						(5.3)
Balance as of June 30,			$6.1						$12.5						$1.1						($0.2)						$2.6

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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 six months ended June 30, 2021.

			Entergy Arkansas						Entergy Louisiana						Entergy Mississippi						Entergy New Orleans						Entergy Texas
			(In Millions)
Balance as of January 1,			$2.7						$4.2						$0.6						$0.1						$1.6
Issuances of financial transmission rights			2.8						4.1						1.7						0.4						2.7
Gains (losses) included as a regulatory liability/asset			27.8						14.7						7.7						2.1						82.2
Settlements			(29.5)						(18.2)						(7.9)						(2.0)						(82.7)
Balance as of June 30,			$3.8						$4.8						$2.1						$0.6						$3.8

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 six months ended June 30, 2020.

			Entergy Arkansas						Entergy Louisiana						Entergy Mississippi						Entergy New Orleans						Entergy Texas
			(In Millions)
Balance as of January 1,			$3.3						$4.5						$0.8						$0.3						$0.9
Issuances of financial transmission rights			6.5						13.2						1.4						(0.1)						2.4
Gains (losses) included as a regulatory liability/asset			5.7						5.5						(1.6)						0.2						6.9
Settlements			(9.4)						(10.7)						0.5						(0.6)						(7.6)
Balance as of June 30,			$6.1						$12.5						$1.1						($0.2)						$2.6

NOTE 9.  DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

The NRC requires Entergy subsidiaries to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents.

As discussed in Note 14 to the financial statements herein, in May 2021, Entergy completed the transfer of Indian Point 1, Indian Point 2, and Indian Point 3 to Holtec. As part of the transaction, Entergy transferred the Indian Point 1, Indian Point 2, and Indian Point 3 decommissioning trust funds to Holtec. The disposition-date fair value of the decommissioning trust funds was approximately $2,387 million.

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 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant.  Decommissioning trust funds for the Entergy Wholesale Commodities nuclear plants do not meet the criteria for regulatory accounting treatment.  Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in

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the accumulated other comprehensive income component of shareholders’ equity.  Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the 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. A portion of Entergy’s decommissioning trust funds were held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company were recognized in earnings. In December 2020, Entergy liquidated its interest in the registered investment company. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $228 million and $389 million, respectively. 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 equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances.

The available-for-sale securities held as of June 30, 2021 and December 31, 2020 are summarized as follows:

						Fair Value						Total Unrealized Gains						Total Unrealized Losses
						(In Millions)
2021
Debt Securities						$2,038						$92						$8
2020
Debt Securities						$2,617						$197						$3

The unrealized gains/(losses) above are reported before deferred taxes of $5 million as of June 30, 2021 and $31 million as of December 31, 2020 for debt securities. The amortized cost of available-for-sale debt securities was $1,954 million as of June 30, 2021 and $2,423 million as of December 31, 2020.  As of June 30, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.82%, an average duration of approximately 6.94 years, and an average maturity of approximately 10.75 years.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020:

						June 30, 2021												December 31, 2020
						Fair Value						Gross Unrealized Losses						Fair Value						Gross Unrealized Losses
						(In Millions)
Less than 12 months						$482						$8						$187						$3
More than 12 months						3						—						2						—
Total						$485						$8						$189						$3

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The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows:

			2021						2020
			(In Millions)
Less than 1 year			$—						($4)
1 year - 5 years			455						672
5 years - 10 years			663						852
10 years - 15 years			335						377
15 years - 20 years			117						144
20 years+			468						576
Total			$2,038						$2,617

During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $273 million and $276 million, respectively.  During the three months ended June 30, 2021 and 2020, gross gains of $6 million and $15 million, respectively, and gross losses of $1 million and $1 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $797 million and $676 million, respectively.  During the six months ended June 30, 2021 and 2020, gross gains of $17 million and $29 million, respectively, and gross losses of $12 million and $4 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

The fair value of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plant as of June 30, 2021 was $564 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2020 were $631 million for Indian Point 1, $794 million for Indian Point 2, $991 million for Indian Point 3, and $554 million for Palisades. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below.

Entergy Arkansas

Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of June 30, 2021 and December 31, 2020 are summarized as follows:

						Fair Value						Total Unrealized Gains						Total Unrealized Losses
						(In Millions)
2021
Debt Securities						$472.5						$16.7						$2.7
2020
Debt Securities						$447.9						$27.7						$0.3

The amortized cost of available-for-sale debt securities was $458.5 million as of June 30, 2021 and $420.4 million as of December 31, 2020.  As of June 30, 2021, available-for-sale debt securities had an average coupon rate

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of approximately 2.45%, an average duration of approximately 6.88 years, and an average maturity of approximately 8.14 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $64.3 million and $109.9 million, respectively. 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 equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020:

						June 30, 2021												December 31, 2020
						Fair Value						Gross Unrealized Losses						Fair Value						Gross Unrealized Losses
						(In Millions)
Less than 12 months						$127.7						$2.7						$29.9						$0.3
More than 12 months						2.0						—						—						—
Total						$129.7						$2.7						$29.9						$0.3

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows:

			2021						2020
			(In Millions)
Less than 1 year			$—						$—
1 year - 5 years			93.6						113.1
5 years - 10 years			191.6						189.8
10 years - 15 years			121.5						81.4
15 years - 20 years			28.8						28.5
20 years+			37.0						35.1
Total			$472.5						$447.9

During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $12.3 million and $17.7 million, respectively.  During the three months ended June 30, 2021 and 2020, gross gains of $0.7 million and $1.3 million, respectively, and gross losses of $0.1 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $26.1 million and $66.4 million, respectively.  During the six months ended June 30, 2021 and 2020, gross gains of $1.6 million and $5.8 million, respectively, and gross losses of $0.1 million and $0.2 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

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Entergy Louisiana

Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of June 30, 2021 and December 31, 2020 are summarized as follows:

						Fair Value						Total Unrealized Gains						Total Unrealized Losses
						(In Millions)
2021
Debt Securities						$697.5						$38.4						$1.9
2020
Debt Securities						$632.2						$51.3						$0.5

The amortized cost of available-for-sale debt securities was $661 million as of June 30, 2021 and $581.4 million as of December 31, 2020.  As of June 30, 2021, the available-for-sale debt securities had an average coupon rate of approximately 3.44%, an average duration of approximately 6.77 years, and an average maturity of approximately 12.32 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $92.9 million and $157.4 million, respectively. 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 equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020:

						June 30, 2021												December 31, 2020
						Fair Value						Gross Unrealized Losses						Fair Value						Gross Unrealized Losses
						(In Millions)
Less than 12 months						$124.4						$1.9						$36.4						$0.5
More than 12 months						0.7						—						0.8						—
Total						$125.1						$1.9						$37.2						$0.5

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The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows:

			2021						2020
			(In Millions)
Less than 1 year			$—						$—
1 year - 5 years			122.7						117.0
5 years - 10 years			188.4						159.4
10 years - 15 years			103.5						101.2
15 years - 20 years			74.3						66.9
20 years+			208.6						187.7
Total			$697.5						$632.2

During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $62.5 million and $34.1 million, respectively.  During the three months ended June 30, 2021 and 2020, gross gains of $1.5 million and $2 million, respectively, and gross losses of $0.1 million and $0.1 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $170.9 million and $101.5 million, respectively.  During the six months ended June 30, 2021 and 2020, gross gains of $4.8 million and $4.9 million, respectively, and gross losses of $3.3 million and $0.7 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

System Energy

System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of June 30, 2021 and December 31, 2020 are summarized as follows:

						Fair Value						Total Unrealized Gains						Total Unrealized Losses
						(In Millions)
2021
Debt Securities						$467.8						$19.4						$2.5
2020
Debt Securities						$427.7						$30.0						$0.8

The amortized cost of available-for-sale debt securities was $450.9 million as of June 30, 2021 and $398.4 million as of December 31, 2020.  As of June 30, 2021, available-for-sale debt securities had an average coupon rate of approximately 2.43%, an average duration of approximately 7.27 years, and an average maturity of approximately 10.68 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2021 on equity securities still held as of June 30, 2021 were $60.6 million and $103.3 million, respectively. 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 equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

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The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2021 and December 31, 2020:

						June 30, 2021												December 31, 2020
						Fair Value						Gross Unrealized Losses						Fair Value						Gross Unrealized Losses
			(In Millions)
Less than 12 months						$149.1						$2.5						$28.9						$0.8
More than 12 months						0.1						—						—						—
Total						$149.2						$2.5						$28.9						$0.8

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2021 and December 31, 2020 were as follows:

			2021						2020
			(In Millions)
Less than 1 year			$—						($1.1)
1 year - 5 years			144.0						134.7
5 years - 10 years			147.3						141.5
10 years - 15 years			46.3						31.5
15 years - 20 years			2.8						5.3
20 years+			127.4						115.8
Total			$467.8						$427.7

During the three months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $101.6 million and $73.6 million, respectively.  During the three months ended June 30, 2021 and 2020, gross gains of $1.9 million and $5.4 million, respectively, and gross losses of $0.2 million and $0.2 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

During the six months ended June 30, 2021 and 2020, proceeds from the dispositions of available-for-sale securities amounted to $175.7 million and $165.6 million, respectively.  During the six months ended June 30, 2021 and 2020, gross gains of $3.1 million and $7 million, respectively, and gross losses of $1.8 million and $0.4 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

Allowance for expected credit losses

Entergy estimates the expected credit losses for its available-for-sale securities based on the current credit rating and remaining life of the securities.  To the extent an individual security is determined to be uncollectible it is written off against this allowance.  Entergy’s available-for-sale securities are held in trusts managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.  Specifically, available-for-sale securities are subject to credit worthiness restrictions, with requirements for both the average credit rating of the portfolio and minimum credit ratings for individual debt securities.  As of June 30, 2021 and December 31, 2020, Entergy’s allowance for expected credit losses related to available-for-sale securities were $0.2 million and $0.1 million, respectively. Entergy did not record any impairments of available-for-sale debt securities for the three and six months ended June 30, 2021 and 2020.

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Notes to Financial Statements

NOTE 10.  INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion.

Tax Cuts and Jobs Act

During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:

			Three Months Ended June 30,												Six Months Ended June 30,
			2021						2020						2021						2020
			(In Millions)
Entergy			$14						$15						$54						$45
Entergy Arkansas			$—						($1)						$8						$12
Entergy Louisiana			$8						$8						$15						$16
Entergy New Orleans			$—						$2						$—						$5
Entergy Texas			$6						$6						$13						$12
System Entergy			$—						$—						$18						$—

Valuation Allowance

During the second quarter 2021, Entergy reduced a valuation allowance by $9 million recorded on the deferred tax asset for a carryover of interest expense because new information indicates that there is sufficient taxable income of a nature that allows for carryover utilization.

NOTE 11.  PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Construction Expenditures in Accounts Payable

Construction expenditures included in accounts payable at June 30, 2021 were $254 million for Entergy, $35.3 million for Entergy Arkansas, $95.7 million for Entergy Louisiana, $26.3 million for Entergy Mississippi, $3.8 million for Entergy New Orleans, $45 million for Entergy Texas, and $16.7 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2020 were $745 million for Entergy, $59.7 million for Entergy Arkansas, $460.5 million for Entergy Louisiana, $31.4 million for Entergy Mississippi, $9.2 million for Entergy New Orleans, $116.8 million for Entergy Texas, and $17.7 million for System Energy.

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NOTE 12.  VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the six months ended June 30, 2021 and in the six months ended June 30, 2020.

NOTE 13.  REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended June 30, 2021 and 2020 were as follows:

						2021						2020
						(In Thousands)
Utility:
Residential						$855,586						$790,869
Commercial						628,703						526,121
Industrial						756,959						576,203
Governmental						61,612						46,959
Total billed retail						2,302,860						1,940,152
Sales for resale (a)						119,130						52,761
Other electric revenues (b)						187,078						168,721
Revenues from contracts with customers						2,609,068						2,161,634
Other revenues (c)						32,307						28,923
Total electric revenues						2,641,375						2,190,557
Natural gas						31,998						22,495
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)						146,680						175,720
Other revenues (c)						2,017						24,016
Total competitive businesses revenues						148,697						199,736
Total operating revenues						$2,822,070						$2,412,788

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Notes to Financial Statements

Entergy’s total revenues for the six months ended June 30, 2021 and 2020 were as follows:

						2021						2020
						(In Thousands)
Utility:
Residential						$1,822,441						$1,588,897
Commercial						1,201,380						1,065,061
Industrial						1,354,610						1,133,718
Governmental						118,409						99,541
Total billed retail						4,496,840						3,887,217
Sales for resale (a)						324,205						106,487
Other electric revenues (b)						267,339						218,887
Revenues from contracts with customers						5,088,384						4,212,591
Other revenues (c)						91,410						28,605
Total electric revenues						5,179,794						4,241,196
Natural gas						90,166						66,471
Entergy Wholesale Commodities:
Competitive businesses sales from contracts with customers (a)						378,794						391,723
Other revenues (c)						18,153						140,577
Total competitive businesses revenues						396,947						532,300
Total operating revenues						$5,666,907						$4,839,967

The Registrant Subsidiaries’ total revenues for the three months ended June 30, 2021 and 2020 were as follows:

2021						Entergy Arkansas						Entergy Louisiana						Entergy Mississippi						Entergy New Orleans						Entergy Texas
						(In Thousands)
Residential						$171,103						$340,643						$117,461						$60,186						$166,193
Commercial						111,187						262,351						101,644						51,092						102,429
Industrial						114,284						475,185						36,545						8,028						122,917
Governmental						4,536						21,547						10,873						18,312						6,344
Total billed retail						401,110						1,099,726						266,523						137,618						397,883
Sales for resale (a)						69,750						74,343						44,050						12,810						19,542
Other electric revenues (b)						73,209						55,745						36,390						9,510						13,577
Revenues from contracts with customers						544,069						1,229,814						346,963						159,938						431,002
Other revenues (c)						6,205						24,765						2,077						(177)						(568)
Total electric revenues						550,274						1,254,579						349,040						159,761						430,434
Natural gas						—						13,019						—						18,979						—
Total operating revenues						$550,274						$1,267,598						$349,040						$178,740						$430,434

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2020						Entergy Arkansas						Entergy Louisiana						Entergy Mississippi						Entergy New Orleans						Entergy Texas
						(In Thousands)
Residential						$171,171						$301,105						$112,361						$53,420						$152,811
Commercial						106,104						209,119						89,594						36,401						84,904
Industrial						106,254						335,201						35,874						3,066						95,809
Governmental						4,344						16,781						9,798						10,475						5,560
Total billed retail						387,873						862,206						247,627						103,362						339,084
Sales for resale (a)						36,956						82,698						18,426						8,018						13,187
Other electric revenues (b)						63,537						53,104						29,393						3,999						20,039
Revenues from contracts with customers						488,366						998,008						295,446						115,379						372,310
Other revenues (c)						3,401						3,593						2,508						19,520						(116)
Total electric revenues						491,767						1,001,601						297,954						134,899						372,194
Natural gas						—						10,051						—						12,444						—
Total operating revenues						$491,767						$1,011,652						$297,954						$147,343						$372,194

The Registrant Subsidiaries’ total revenues for the six months ended June 30, 2021 and 2020 were as follows:

2021						Entergy Arkansas						Entergy Louisiana						Entergy Mississippi						Entergy New Orleans						Entergy Texas
						(In Thousands)
Residential						$408,284						$676,403						$265,097						$126,613						$346,044
Commercial						217,603						487,000						199,580						98,891						198,306
Industrial						217,696						822,194						70,524						14,817						229,379
Governmental						8,791						40,163						21,416						34,692						13,347
Total billed retail						852,374						2,025,760						556,617						275,013						787,076
Sales for resale (a)						179,834						154,771						84,360						17,506						93,615
Other electric revenues (b)						92,791						99,654						40,341						6,151						31,106
Revenues from contracts with customers						1,124,999						2,280,185						681,318						298,670						911,797
Other revenues (c)						8,661						54,057						4,341						239						(1,143)
Total electric revenues						1,133,660						2,334,242						685,659						298,909						910,654
Natural gas						—						41,000						—						49,166						—
Total operating revenues						$1,133,660						$2,375,242						$685,659						$348,075						$910,654

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2020						Entergy Arkansas						Entergy Louisiana						Entergy Mississippi						Entergy New Orleans						Entergy Texas
						(In Thousands)
Residential						$390,859						$560,965						$239,463						$104,319						$293,291
Commercial						217,349						411,365						186,392						81,905						168,050
Industrial						207,342						657,542						72,264						10,413						186,157
Governmental						8,374						33,535						20,125						26,326						11,180
Total billed retail						823,924						1,663,407						518,244						222,963						658,678
Sales for resale (a)						78,096						161,228						32,848						18,188						21,815
Other electric revenues (b)						65,134						85,113						35,836						4,763						30,742
Revenues from contracts with customers						967,154						1,909,748						586,928						245,914						711,235
Other revenues (c)						6,525						4,394						4,948						12,416						295
Total electric revenues						973,679						1,914,142						591,876						258,330						711,530
Natural gas						—						28,157						—						38,315						—
Total operating revenues						$973,679						$1,942,299						$591,876						$296,645						$711,530

(a)Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.

(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.

(c)Other revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

Allowance for doubtful accounts

The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. Due to the essential nature of utility services, Entergy has historically experienced a low rate of default on its accounts receivables. Due to the effect of the COVID-19 pandemic on customer receivables, however, Entergy recorded increases in its allowance for doubtful accounts in 2020. The following table sets forth a reconciliation of changes in the allowance for doubtful accounts for the six months ended June 30, 2021 and 2020.

			Entergy						Entergy Arkansas						Entergy Louisiana						Entergy Mississippi						Entergy New Orleans						Entergy Texas
			(In Millions)
Balance as of December 31, 2020			$117.7						$18.3						$45.7						$19.5						$17.4						$16.8
Provisions			25.9						5.5						11.7						1.7						4.6						2.4
Write-offs			(39.5)						(2.8)						(19.5)						(8.8)						(1.1)						(7.3)
Recoveries			5.0						1.4						1.9						1.2						0.2						0.3
Balance as of June 30, 2021			$109.1						$22.4						$39.8						$13.6						$21.1						$12.2

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			Entergy						Entergy Arkansas						Entergy Louisiana						Entergy Mississippi						Entergy New Orleans						Entergy Texas
			(In Millions)
Balance as of December 31, 2019			$7.4						$1.2						$1.9						$0.6						$3.2						$0.5
Provisions			38.4						6.3						14.1						7.0						5.5						5.5
Write-offs			(8.6)						(1.8)						(3.5)						(1.2)						(1.0)						(1.1)
Recoveries			6.0						1.6						2.0						0.8						0.7						0.9
Balance as of June 30, 2020			$43.2						$7.3						$14.5						$7.2						$8.4						$5.8

The allowance for currently expected credit losses is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner.

NOTE 14.  ACQUISITIONS AND DISPOSITIONS (Entergy Corporation and Entergy Texas)

Acquisitions

Hardin County Peaking Facility

In June 2021, Entergy Texas purchased the Hardin County Peaking Facility, an existing 147 MW simple-cycle gas-fired peaking power plant in Kountze, Texas, from East Texas Electric Cooperative, Inc. In addition, also in June 2021, Entergy Texas sold a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc. for approximately $67.9 million. The two interdependent transactions were approved by the PUCT in April 2021. The purchase price for the Hardin County Peaking Facility was approximately $36.7 million.

Dispositions

Indian Point Energy Center

In April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3, after Indian Point 3 had been shut down and defueled, to a Holtec International subsidiary. In November 2020 the NRC approved the sale of the plant to Holtec. Indian Point 3 was shut down in April 2021 and defueled in May 2021. In May 2021 the New York State Public Service Commission approved the sale of the plant to Holtec. The transaction closed in May 2021. The sale included the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units. The transaction resulted in a charge of $340 million ($268 million net-of-tax) in the second quarter of 2021. The disposition-date fair value of the nuclear decommissioning trust funds was approximately $2,387 million and the disposition-date fair value of the asset retirement obligations was $1,996 million. The transaction also included materials and supplies and prepaid assets.

________________

In the opinion of the management of Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy, the accompanying unaudited financial statements contain all adjustments (consisting primarily of normal recurring accruals and reclassification of previously reported amounts to conform to current classifications) necessary for a fair statement of the results for

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Notes to Financial Statements

the interim periods presented.  Entergy’s business is subject to seasonal fluctuations, however, with peak periods occurring typically during the first and third quarters.  The results for the interim periods presented should not be used as a basis for estimating results of operations for a full year.

Part I, Item 3. Quantitative and Qualitative Disclosures About Market Risk

See “Market and Credit Risk Sensitive Instruments” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis.

Part I, Item 4. Controls and Procedures

Disclosure Controls and Procedures

As of June 30, 2021, evaluations were performed under the supervision and with the participation of Entergy Corporation, Entergy Arkansas, 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.

Changes in Internal Controls over Financial Reporting

Under the supervision and with the participation of each Registrants’ management, including its respective PEO and PFO, each Registrant evaluated changes in internal control over financial reporting that occurred during the quarter ended June 30, 2021 and found no change that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

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MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy Arkansas’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy Arkansas were approximately $145 million in February 2021 compared to approximately $40 million in February 2020. See Note 2 to the financial statements herein and in the Form 10-K for discussion of fuel cost recovery at Entergy Arkansas.

In March 2021 the APSC opened an investigation into Arkansas utilities’ preparation, response, operational performance, and communication regarding the February 2021 extreme weather events. Comments from jurisdictional utilities are due in August 2021. In April 2021, the Arkansas Attorney General notified utilities of its intent to conduct an investigation into the fuel costs that were charged during the February 2021 winter storms; specifically, whether there was price gouging by suppliers.

Results of Operations

Net Income

Second Quarter 2021 Compared to Second Quarter 2020

Net income decreased $3.6 million primarily due to lower other income, higher other operation and maintenance expenses, and higher depreciation and amortization expenses, partially offset by higher retail electric price and higher volume/weather.

Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020

Net income increased $44.9 million primarily due to higher volume/weather, the reversal in 2021 of the remaining regulatory liability for the formula rate plan 2019 historical year netting adjustment, and higher retail electric price, partially offset by a higher effective income tax rate, higher other operation and maintenance expenses, and higher depreciation and amortization expenses.

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Management's Financial Discussion and Analysis

Operating Revenues

Second Quarter 2021 Compared to Second Quarter 2020

Following is an analysis of the change in operating revenues comparing the second quarter 2021 to the second quarter 2020:

			Amount
			(In Millions)
2020 operating revenues			$491.8
Fuel, rider, and other revenues that do not significantly affect net income			40.7
Retail electric price			9.8
Volume/weather			8.0
2021 operating revenues			$550.3

Entergy Arkansas’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The retail electric price variance is primarily due to an increase in formula rate plan rates effective with the first billing cycle of May 2021. See Note 2 to the financial statements herein for further discussion of the 2020 formula rate plan filing.

The volume/weather variance is primarily due to an increase of 396 GWh, or 9%, in billed electricity usage primarily due to an increase in commercial usage resulting from reduced impacts from the COVID-19 pandemic on businesses as compared to prior year and an increase in industrial usage. The increase in industrial usage is primarily due to an increase in demand from expansion projects, primarily in the metals industry. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Billed electric energy sales for Entergy Arkansas for the three months ended June 30, 2021 and 2020 are as follows:

			2021						2020						% Change
			(GWh)
Residential			1,487						1,497						(1)
Commercial			1,260						1,176						7
Industrial			2,059						1,738						18
Governmental			53						52						2
Total retail			4,859						4,463						9
Sales for resale:
Associated companies			525						308						70
Non-associated companies			1,700						831						105
Total			7,084						5,602						26

See Note 13 to the financial statements herein for additional discussion of Entergy Arkansas’s operating revenues.

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Management's Financial Discussion and Analysis

Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020

Following is an analysis of the change in operating revenues comparing the six months ended June 30, 2021 to the six months ended June 30, 2020:

			Amount
			(In Millions)
2020 operating revenues			$973.7
Fuel, rider, and other revenues that do not significantly affect net income			109.0
Volume/weather			44.0
Retail electric price			7.0
2021 operating revenues			$1,133.7

Entergy Arkansas’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The volume/weather variance is primarily due to an increase of 870 GWh, or 9%, in billed electricity usage, including the effect of more favorable weather on residential sales and increased industrial usage. The increase in industrial usage is primarily due to an increase in demand from expansion projects, primarily in the metals industry.

The retail electric price variance is primarily due to an increase in formula rate plan rates effective with the first billing cycle of May 2021. See Note 2 to the financial statements herein for further discussion of the 2020 formula rate plan filing.

Billed electric energy sales for Entergy Arkansas for the six months ended June 30, 2021 and 2020 are as follows:

			2021						2020						% Change
			(GWh)
Residential			3,957						3,572						11
Commercial			2,525						2,460						3
Industrial			3,968						3,549						12
Governmental			107						106						1
Total retail			10,557						9,687						9
Sales for resale:
Associated companies			1,122						711						58
Non-associated companies			3,731						1,977						89
Total			15,410						12,375						25

See Note 13 to the financial statements herein for additional discussion of Entergy Arkansas’s operating revenues.

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Other Income Statement Variances

Second Quarter 2021 Compared to Second Quarter 2020

Other operation and maintenance expenses increased primarily due to:

•an increase of $3.4 million in compensation and benefits costs primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs; and

•an increase of $3.1 million in non-nuclear generation expenses due to a higher scope of work performed during plant outages in 2021 as compared to 2020.

Depreciation and amortization expenses increased primarily due to additions to plant in service.

Other regulatory charges (credits) - net for the second quarter of 2020 includes regulatory credits of $10.5 million to reflect the amortization of the 2018 historical year netting adjustment reflected in the 2019 formula rate plan filing. See Note 2 to the financial statements in the Form 10-K for discussion of the 2019 formula rate plan filing.

Other income decreased primarily due to changes in decommissioning trust fund investment activity.

Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020

Other operation and maintenance expenses increased primarily due to:

•lower nuclear insurance refunds of $5.8 million;

•an increase of $4.9 million in non-nuclear generation expenses due to a higher scope of work performed during plant outages in 2021 as compared to 2020;

•an increase of $3.9 million in compensation and benefits costs primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs; and

•an increase of $2.2 million in vegetation maintenance costs.

The increase was partially offset by a decrease of $3.9 million in nuclear generation expenses primarily due to lower nuclear labor costs and a lower scope of work performed in 2021 as compared to 2020.

Depreciation and amortization expenses increased primarily due to additions to plant in service.

Other regulatory charges (credits) - net for the six months ended June 30, 2021 includes the reversal of the remaining $38.8 million regulatory liability for the 2019 historical year netting adjustment as part of its 2020 formula rate plan proceeding. See Note 2 to the financial statements herein and in the Form 10-K for discussion of the 2020 formula rate plan filing. Other regulatory charges (credits) - net for the six months ended June 30, 2020 includes regulatory credits of $22.2 million to reflect the amortization of the 2018 historical year netting adjustment reflected in the 2019 formula rate plan filing. See Note 2 to the financial statements in the Form 10-K for

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discussion of the 2019 formula rate plan filing.

Other income increased primarily due to changes in decommissioning trust fund investment activity.

Income Taxes

The effective income tax rate was 20.9% for the second quarter 2021. The difference in the effective income tax rate for the second quarter 2021 versus the federal statutory rate of 21% was primarily due to certain book and tax differences related to utility plant items and book and tax differences related to the allowance for equity funds used during construction, offset by state income taxes.

The effective income tax rate was 18.7% for the six months ended June 30, 2021. The difference in the effective income tax rate for the six months ended June 30, 2021 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes and certain book and tax differences related to utility plant items, partially offset by state income taxes. See Note 10 to the financial statements herein and Note 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was 24.5% for the second quarter 2020. The difference in the effective income tax rate for the second quarter 2020 versus the federal statutory rate of 21% was primarily due to state income taxes, partially offset by certain book and tax differences related to utility plant items.

The effective income tax rate was 10.9% for the six months ended June 30, 2020. The difference in the effective income tax rate for the six months ended June 30, 2020 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, certain book and tax differences related to utility plant items, and permanent differences related to income tax deductions for stock-based compensation, partially offset by state income taxes. See Note 10 to the financial statements herein and Note 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 3 to the financial statements in the Form 10-K for discussion of the income tax deductions for stock-based compensation.

Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2021 and 2020 were as follows:

			2021						2020
			(In Thousands)
Cash and cash equivalents at beginning of period			$192,128						$3,519
Cash flow provided by (used in):
Operating activities			164,633						287,031
Investing activities			(326,706)						(400,864)
Financing activities			95,071						112,887
Net decrease in cash and cash equivalents			(67,002)						(946)
Cash and cash equivalents at end of period			$125,126						$2,573

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Operating Activities

Net cash flow provided by operating activities decreased $122.4 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to:

•increased fuel costs as a result of Winter Storm Uri. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of fuel and purchased power cost recovery;

•the timing of collections of receivables from customers, in part due to the COVID-19 pandemic;

•$25 million in proceeds received from the DOE in 2020 resulting from litigation regarding spent nuclear fuel storage costs that were previously expensed. See Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation; and

•an increase of $18.9 million in pension contributions in 2021. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding.

The decrease was partially offset by the timing of payments to vendors.

Investing Activities

Net cash flow used in investing activities decreased $74.2 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to:

•a decrease of $59.5 million in storm spending;

•a decrease of $30.4 million as a result of fluctuations in nuclear fuel activity because of variations from year to year in the timing and pricing of fuel reload requirements in the Utility business, material and service deliveries, and the timing of cash payments during the nuclear fuel cycle;

•a decrease of $24.3 million in transmission construction expenditures primarily due to a lower scope of work performed in 2021 as compared to 2020; and

•a decrease of $17.2 million in information technology expenditures primarily due to decreased spending on various technology projects.

The decrease was partially offset by:

•$55 million in proceeds received from the DOE in 2020 resulting from litigation regarding spent nuclear fuel storage costs that were previously capitalized. See Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation; and

•an increase of $28.2 million in distribution construction expenditures primarily due to investment in the reliability and infrastructure of Entergy Arkansas’s distribution system.

Financing Activities

Net cash flow provided by financing activities decreased $17.8 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to:

•the repayment, at maturity, of $350 million of 3.75% Series mortgage bonds due February 2021;

•issuance of $100 million of 4.00% Series mortgage bonds in March 2020;

•the repayment, at maturity, of $45 million of 2.375% governmental bonds due January 2021; and

•net repayments of long-term borrowings of $12.2 million in 2021 compared to net long-term borrowings of $8.6 million in 2020 on the Entergy Arkansas nuclear fuel company variable interest entity credit facility.

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The decrease was partially offset by the issuance of $400 million of 3.35% Series mortgage bonds in March 2021 and the issuance of $90 million of 1.84% Series N notes payable in June 2021 by the Entergy Arkansas nuclear fuel company variable interest entity.

See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

Capital Structure

Entergy Arkansas’s debt to capital ratio is shown in the following table.

			June 30, 2021						December 31, 2020
Debt to capital			54.2		%				54.8		%
Effect of subtracting cash			(0.8		%)				(1.2		%)
Net debt to net capital			53.4		%				53.6		%

Net debt consists of debt less cash and cash equivalents.  Debt consists of short-term borrowings, finance 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 Arkansas uses the debt to capital ratio in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy Arkansas’s financial condition.  Entergy Arkansas also 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 because net debt indicates Entergy Arkansas’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Arkansas’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.

Entergy Arkansas’s receivables from or (payables to) the money pool were as follows:

June 30, 2021						December 31, 2020						June 30, 2020						December 31, 2019
(In Thousands)
$8,196						$3,110						($25,865)						($21,634)

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Entergy Arkansas has a credit facility in the amount of $150 million scheduled to expire in June 2026. Entergy Arkansas also has a $25 million credit facility scheduled to expire in April 2022. The $150 million credit facility includes fronting commitments for the issuance of letters of credit against $5 million of the borrowing capacity of the facility. As of June 30, 2021, no cash borrowings and no letters of credit were outstanding under the credit facilities. In addition, Entergy Arkansas is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of June 30, 2021, a $2.5 million letter of credit was outstanding under Entergy Arkansas’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

The Entergy Arkansas nuclear fuel company variable interest entity has a credit facility in the amount of $80 million scheduled to expire in June 2024.  As of June 30, 2021, there were no loans outstanding under the credit

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facility for the Entergy Arkansas nuclear fuel company variable interest entity. See Note 4 to the financial statements herein for additional discussion of the nuclear fuel company variable interest entity credit facility.

Searcy Solar Facility

As discussed in the Form 10-K, in April 2020 the APSC issued an order approving Entergy Arkansas’s acquisition of the Searcy Solar facility as being in the public interest. In May 2021, Entergy Arkansas filed with the APSC an application seeking to amend its certificate for the Searcy Solar facility to allow for the use of a tax equity partnership. The tax equity partnership structure is expected to reduce costs and yield incremental net benefits to customers beyond those expected under the build-own-transfer structure alone. A decision on the tax equity partnership is requested by September 2021. Entergy Arkansas will purchase the facility upon mechanical completion and after the other purchase contingencies have been met. Closing is expected to occur by the end of 2021.

Walnut Bend Solar Facility

In October 2020, Entergy Arkansas filed a petition with the APSC seeking a finding that the purchase of the 100 MW Walnut Bend Solar Facility is in the public interest. Entergy Arkansas primarily requested cost recovery through the formula rate plan rider. A procedural schedule was established with a paper hearing held in April 2021. In July 2021 the APSC granted Entergy Arkansas’s petition and approved the acquisition of the resource and cost recovery through the formula rate plan rider. In addition, the APSC directed Entergy Arkansas to file a report within 180 days detailing its efforts to obtain a tax equity partnership. Closing is expected to occur in 2022.

State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – State and Local Rate Regulation and Fuel-Cost Recovery” in the Form 10-K for a discussion of state and local rate regulation and fuel-cost recovery.  The following are updates to that discussion.

Retail Rates

2020 Formula Rate Plan Filing

As discussed in the Form 10-K, in December 2020, Entergy Arkansas filed a petition for rehearing of the APSC’s decision in the 2020 formula rate plan proceeding regarding the 2019 netting adjustment, and in January 2021 the APSC granted further consideration of Entergy Arkansas’s petition. Based on the progress of the proceeding to date, in December 2020, Entergy Arkansas recorded a regulatory liability of $43.5 million to reflect the netting adjustment for 2019, as included in the APSC’s December 2020 order, which would be returned to customers in 2021. Entergy Arkansas also requested an extension of the formula rate plan rider for a second five-year term. In March 2021, the Arkansas Governor signed HB1662 into law (Act 404). Act 404 clarified aspects of the original formula rate plan legislation enacted in 2015, including with respect to the extension of a formula rate plan, the methodology for the netting adjustment, and debt and equity levels; it also reaffirmed the customer protections of the original formula rate plan legislation, including the cap on annual formula rate plan rate changes. Pursuant to Act 404, Entergy Arkansas’s formula rate plan rider is extended for a second five-year term. Entergy Arkansas filed a compliance tariff in its formula rate plan docket in April 2021 to effectuate the netting provisions of Act 404, which reflected a net change in required formula rate plan rider revenue of $39.8 million, effective with the first billing cycle of May 2021. In April 2021 the APSC issued an order approving the compliance tariff and recognizing the formula rate plan extension. Also in April 2021, Entergy Arkansas filed for approval of modifications to the formula rate plan tariff incorporating the provisions in Act 404, and the APSC approved the tariff modifications in April 2021. Given the APSC general staff’s support for the expedited approval of these filings by the APSC, Entergy Arkansas supported an amendment to Act 404 to achieve a reduced return on equity from 9.75% to 9.65% to apply for years applicable to the extension term; that amendment was signed by the

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Arkansas Governor in April 2021 and is now Act 894. Based on the APSC’s order issued in April 2021, in the first quarter 2021, Entergy Arkansas reversed the remaining regulatory liability for the netting adjustment for 2019. In June 2021, Entergy Arkansas filed another compliance tariff in its formula rate plan proceeding to effectuate the additional provisions of Act 894, and the APSC approved the second compliance tariff filing in July 2021.

2021 Formula Rate Plan Filing

In July 2021, Entergy Arkansas filed with the APSC its 2021 formula rate plan filing to set its formula rate for the 2022 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2022 and a netting adjustment for the historical year 2020. The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2022 projected year is 7.65% resulting in a revenue deficiency of $89.2 million. The earned rate of return on common equity for the 2020 historical year was 7.92% resulting in a $19.4 million netting adjustment. The total proposed revenue change for the 2022 projected year and 2020 historical year netting adjustment is $108.7 million. By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint. Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase is limited to $72.6 million. An order is requested by December 2021.

Energy Cost Recovery Rider

In March 2021, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01052 per kWh to $0.00959 per kWh. The redetermined rate calculation also included an adjustment to account for a portion of the increased fuel costs resulting from the February 2021 winter storms. The redetermined rate became effective with the first billing cycle in April 2021 through the normal operation of the tariff.

Opportunity Sales Proceeding

As discussed in the Form 10-K, the FERC’s opportunity sales orders have been appealed to the D.C. Circuit. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders.

As discussed in the Form 10-K, in May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover from its retail customers the costs of the opportunity sales payments made to the other Utility operating companies, and in July 2020 the APSC issued a decision finding that Entergy Arkansas’s application is not in the public interest. In September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s order denying Entergy Arkansas’s request to recover the costs of these payments. The court held a hearing in February 2021 regarding issues addressed in the pre-trial conference report, and in June 2021 the court stayed all discovery until it rules on pending motions, after which the court will issue an amended schedule if necessary.

Net Metering Legislation

See the Form 10-K for discussion of Arkansas net metering legislation and subsequent APSC net metering proceedings. In January 2021, Entergy Arkansas, pursuant to an APSC order, filed an updated net metering tariff, which was approved in February 2021. In May 2021, Entergy Arkansas filed a motion to dismiss its pending judicial appeal of the APSC’s September 2020 order on rehearing in the proceeding addressing its net metering rules. In June 2021 the Arkansas Court of Appeals granted the motion and dismissed Entergy Arkansas’s appeal, although other appeals of the September 2020 APSC order remain pending with that court.

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COVID-19 Orders

See the Form 10-K for discussion of APSC orders issued in light of the COVID-19 pandemic. In March 2021 the APSC issued an order confirming the lifting of the moratorium on service disconnects effective in May 2021. As of June 30, 2021, Entergy Arkansas recorded a regulatory asset of $11.2 million for costs associated with the COVID-19 pandemic.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation. 

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy Arkansas’s accounting for nuclear decommissioning costs, utility regulatory accounting, impairment of long-lived assets, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2021 and 2020
(Unaudited)
						Three Months Ended												Six Months Ended
						2021						2020						2021						2020
						(In Thousands)												(In Thousands)
OPERATING REVENUES
Electric						$550,274						$491,767						$1,133,660						$973,679
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale						74,556						52,692						200,737						140,103
Purchased power						61,448						42,171						131,669						88,212
Nuclear refueling outage expenses						13,535						13,552						26,182						29,799
Other operation and maintenance						173,098						164,770						328,006						316,627
Decommissioning						19,280						18,206						38,280						36,147
Taxes other than income taxes						30,106						27,172						59,849						58,232
Depreciation and amortization						90,276						84,538						178,555						168,059
Other regulatory charges (credits) - net						(22,170)						(19,283)						(59,637)						(39,284)
TOTAL						440,129						383,818						903,641						797,895
OPERATING INCOME						110,145						107,949						230,019						175,784
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction						3,608						3,878						6,601						6,795
Interest and investment income						(2,739)						8,246						25,148						16,184
Miscellaneous - net						(5,372)						(6,133)						(11,163)						(12,569)
TOTAL						(4,503)						5,991						20,586						10,410
INTEREST EXPENSE
Interest expense						35,624						35,969						69,410						71,592
Allowance for borrowed funds used during construction						(1,572)						(1,703)						(2,862)						(2,984)
TOTAL						34,052						34,266						66,548						68,608
INCOME BEFORE INCOME TAXES						71,590						79,674						184,057						117,586
Income taxes						14,997						19,504						34,427						12,821
NET INCOME						$56,593						$60,170						$149,630						$104,765
See Notes to Financial Statements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2021 and 2020
(Unaudited)
						2021						2020
						(In Thousands)
OPERATING ACTIVITIES
Net income						$149,630						$104,765
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization						252,537						243,126
Deferred income taxes, investment tax credits, and non-current taxes accrued						50,780						24,970
Changes in assets and liabilities:
Receivables						(86,447)						(10,360)
Fuel inventory						12,996						(12,704)
Accounts payable						27,920						(34,009)
Taxes accrued						(6,529)						(409)
Interest accrued						(2,490)						119
Deferred fuel costs						(74,857)						16,322
Other working capital accounts						(36,703)						(23,858)
Provisions for estimated losses						(6,122)						998
Other regulatory assets						32,837						(26,191)
Other regulatory liabilities						17,776						(50,637)
Pension and other postretirement liabilities						(46,940)						(419)
Other assets and liabilities						(119,755)						55,318
Net cash flow provided by operating activities						164,633						287,031
INVESTING ACTIVITIES
Construction expenditures						(322,044)						(406,940)
Allowance for equity funds used during construction						6,601						6,795
Payment for purchase of assets						—						(5,988)
Nuclear fuel purchases						(25,466)						(57,781)
Proceeds from sale of nuclear fuel						16,239						18,107
Proceeds from nuclear decommissioning trust fund sales						227,807						183,474
Investment in nuclear decommissioning trust funds						(224,757)						(194,776)
Change in money pool receivable - net						(5,086)						—
Changes in securitization account						—						1,244
Litigation proceeds for reimbursement of spent nuclear fuel storage costs						—						55,001
Net cash flow used in investing activities						(326,706)						(400,864)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt						694,137						335,902
Retirement of long-term debt						(618,511)						(226,366)
Changes in money pool payable - net						—						4,231
Other						19,445						(880)
Net cash flow provided by financing activities						95,071						112,887
Net decrease in cash and cash equivalents						(67,002)						(946)
Cash and cash equivalents at beginning of period						192,128						3,519
Cash and cash equivalents at end of period						$125,126						$2,573
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized						$70,700						$69,276
See Notes to Financial Statements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
June 30, 2021 and December 31, 2020
(Unaudited)
						2021						2020
						(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash						$108,882						$24,108
Temporary cash investments						16,244						168,020
Total cash and cash equivalents						125,126						192,128
Accounts receivable:
Customer						208,469						183,719
Allowance for doubtful accounts						(22,395)						(18,334)
Associated companies						48,646						34,216
Other						64,661						35,845
Accrued unbilled revenues						136,598						109,000
Total accounts receivable						435,979						344,446
Deferred fuel costs						21,527						—
Fuel inventory - at average cost						30,815						43,811
Materials and supplies - at average cost						247,633						237,640
Deferred nuclear refueling outage costs						46,996						32,692
Prepayments and other						20,228						13,296
TOTAL						928,304						864,013
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds						1,376,715						1,273,921
Other						339						341
TOTAL						1,377,054						1,274,262
UTILITY PLANT
Electric						13,067,828						12,905,322
Construction work in progress						319,379						234,213
Nuclear fuel						156,819						163,044
TOTAL UTILITY PLANT						13,544,026						13,302,579
Less - accumulated depreciation and amortization						5,384,637						5,255,355
UTILITY PLANT - NET						8,159,389						8,047,224
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets						1,799,547						1,832,384
Deferred fuel costs						68,485						68,220
Other						17,292						14,028
TOTAL						1,885,324						1,914,632
TOTAL ASSETS						$12,350,071						$12,100,131
See Notes to Financial Statements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
June 30, 2021 and December 31, 2020
(Unaudited)
						2021						2020
						(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt						$90,000						$485,000
Accounts payable:
Associated companies						94,710						59,448
Other						183,266						208,591
Customer deposits						92,474						98,506
Taxes accrued						75,308						81,837
Interest accrued						20,255						22,745
Deferred fuel costs						—						53,065
Other						41,682						40,628
TOTAL						597,695						1,049,820
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued						1,346,301						1,286,123
Accumulated deferred investment tax credits						29,899						30,500
Regulatory liability for income taxes - net						446,059						467,031
Other regulatory liabilities						725,620						686,872
Decommissioning						1,352,440						1,314,160
Accumulated provisions						64,047						70,169
Pension and other postretirement liabilities						314,639						361,682
Long-term debt						3,953,714						3,482,507
Other						93,858						75,098
TOTAL						8,326,577						7,774,142
Commitments and Contingencies
EQUITY
Member's equity						3,425,799						3,276,169
TOTAL						3,425,799						3,276,169
TOTAL LIABILITIES AND EQUITY						$12,350,071						$12,100,131
See Notes to Financial Statements.

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CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Six Months Ended June 30, 2021 and 2020
(Unaudited)
						Member's Equity
						(In Thousands)
Balance at December 31, 2019						$3,125,937
Net income						44,595
Balance at March 31, 2020						3,170,532
Net income						60,170
Balance at June 30, 2020						$3,230,702
Balance at December 31, 2020						$3,276,169
Net income						93,037
Balance at March 31, 2021						3,369,206
Net income						56,593
Balance at June 30, 2021						$3,425,799
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Hurricane Laura, Hurricane Delta, and Hurricane Zeta

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Laura, Hurricane Delta, and Hurricane Zeta” in the Form 10-K for a discussion of Hurricane Laura, Hurricane Delta, and Hurricane Zeta, which caused significant damage to portions of Entergy Louisiana’s service area. See Note 2 to the financial statements herein for discussion of storm cost filings made in 2021 by Entergy Louisiana.

Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy Louisiana’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy Louisiana were approximately $285 million in February 2021 compared to approximately $95 million in February 2020. See Note 2 to the financial statements herein for discussion of the storm cost filings made in 2021 by Entergy Louisiana. See Note 2 to the financial statements herein and in the Form 10-K for discussion of fuel cost recovery at Entergy Louisiana.

Results of Operations

Net Income

Second Quarter 2021 Compared to Second Quarter 2020

Net income decreased $26.5 million primarily due to higher other operation and maintenance expenses, higher depreciation and amortization expenses, and higher interest expense. The decrease was partially offset by higher retail electric price.

Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020

Net income decreased $49.3 million primarily due to the $58 million reduction in income tax expense resulting from an IRS settlement in the first quarter 2020 related to the uncertain tax position regarding the Hurricane Isaac Louisiana Act 55 financing, which also resulted in a $29 million ($21 million net-of-tax) regulatory charge to reflect Entergy Louisiana’s agreement to share the savings with customers. Also contributing to the decrease was higher other operation and maintenance expenses, higher depreciation and amortization expenses, and higher interest expense. The decrease was partially offset by higher retail electric price and higher volume/weather. See Note 3 to the financial statements in the Form 10-K for further discussion of the tax settlement.

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Operating Revenues

Second Quarter 2021 Compared to Second Quarter 2020

Following is an analysis of the change in operating revenues comparing the second quarter 2021 to the second quarter 2020:

			Amount
			(In Millions)
2020 operating revenues			$1,011.7
Fuel, rider, and other revenues that do not significantly affect net income			231.9
Retail electric price			27.3
Volume/weather			(3.3)
2021 operating revenues			$1,267.6

Entergy Louisiana’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The retail electric price variance is primarily due to:

•an increase in overall formula rate plan revenues, including an increase in the transmission recovery mechanism, effective September 2020; and

•an interim increase in formula rate plan revenues effective December 2020 due to the inclusion of the first-year revenue requirement for the Washington Parish Energy Center.

See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan proceedings.

The volume/weather variance is primarily due to the effect of less favorable weather on residential and commercial sales and a decrease in residential usage primarily due to the impact that the COVID-19 pandemic had on prior year usage. The decrease is partially offset by an increase in commercial usage resulting from reduced impacts from the COVID-19 pandemic on businesses as compared to prior year and an increase in industrial usage primarily due to increased demand from expansion projects, primarily in the chemicals and transportation industries, and increased demand from existing projects, primarily in the industrial gases and petroleum refining industries. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

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Billed electric energy sales for Entergy Louisiana for the three months ended June 30, 2021 and 2020 are as follows:

			2021						2020						% Change
			(GWh)
Residential			2,969						3,239						(8)
Commercial			2,501						2,455						2
Industrial			7,734						7,427						4
Governmental			202						189						7
Total retail			13,406						13,310						1
Sales for resale:
Associated companies			1,167						1,407						(17)
Non-associated companies			552						544						1
Total			15,125						15,261						(1)

See Note 13 to the financial statements herein for additional discussion of Entergy Louisiana’s operating revenues.

Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020

Following is an analysis of the change in operating revenues comparing the six months ended June 30, 2021 to the six months ended June 30, 2020:

			Amount
			(In Millions)
2020 operating revenues			$1,942.3
Fuel, rider, and other revenues that do not significantly affect net income			324.3
Retail electric price			75.4
Volume/weather			33.2
2021 operating revenues			$2,375.2

Entergy Louisiana’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The retail electric price variance is primarily due to:

•an interim increase in formula rate plan revenues effective April 2020 due to the inclusion of the first-year revenue requirement for the Lake Charles Power Station;

•an increase in overall formula rate plan revenues, including an increase in the transmission recovery mechanism, effective September 2020; and

•an interim increase in formula rate plan revenues effective December 2020 due to the inclusion of the first-year revenue requirement for the Washington Parish Energy Center.

See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan proceedings.

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The volume/weather variance is primarily due to the effect of more favorable weather on residential and commercial sales, increased residential usage, and an increase in usage during the unbilled sales period. The increase is partially offset by a decrease in commercial and industrial usage. The decrease in industrial usage is primarily due to decreased demand from mid to small customers and existing customers in the chemicals and petroleum refining industries as a result of the COVID-19 pandemic and temporary plant shutdowns and operational issues. The decrease in industrial usage is partially offset by an increase in demand from expansion projects, primarily in the transportation and chemicals industries. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Billed electric energy sales for Entergy Louisiana for the six months ended June 30, 2021 and 2020 are as follows:

			2021						2020						% Change
			(GWh)
Residential			6,469						6,214						4
Commercial			4,910						4,914						—
Industrial			14,744						14,877						(1)
Governmental			398						388						3
Total retail			26,521						26,393						—
Sales for resale:
Associated companies			2,126						2,748						(23)
Non-associated companies			938						1,001						(6)
Total			29,585						30,142						(2)

See Note 13 to the financial statements herein for additional discussion of Entergy Louisiana’s operating revenues.

Other Income Statement Variances

Second Quarter 2021 Compared to Second Quarter 2020

Other operation and maintenance expenses increased primarily due to:

•the effects of recording in second quarter 2020 final judgments to resolve claims in the Waterford 3 damages case against the DOE related to spent nuclear fuel storage costs. The damages awarded included the reimbursement of approximately $7.7 million of spent nuclear fuel storage costs previously recorded as other operation and maintenance expense. See Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation;

•an increase of $6.3 million in compensation and benefits costs primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs;

•an increase of $5.1 million in energy efficiency costs due to the timing of recovery from customers;

•an increase of $4.8 million in non-nuclear generation expenses primarily due to a higher scope of work performed during plant outages in 2021 as compared to 2020 and higher expenses associated with plants placed in service, including the Washington Parish Energy Center, purchased in November 2020;

•an increase of $4.4 million in distribution operations expenses primarily due to higher distribution reliability costs;

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•an increase of $2.3 million in information technology costs primarily due to higher contract costs and higher costs associated with system maintenance;

•an increase of $2.1 million primarily due to contract costs in 2021 related to customer solutions and sustainability initiatives;

•an increase of $2.1 million in vegetation maintenance costs; and

•several individually insignificant items.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including Washington Parish Energy Center, which was placed in service in November 2020.

Interest expense increased primarily due to:

•the issuance of $1.1 billion of 0.62% Series mortgage bonds, $300 million of 2.90% Series mortgage bonds, and $300 million of 1.60% Series mortgage bonds, each in November 2020; and

•the issuance of $500 million of 2.35% Series mortgage bonds and $500 million of 3.10% Series mortgage bonds, each in March 2021.

The increase was partially offset by the repayment of $250 million of 3.95% Series mortgage bonds in October 2020, the repayment of $200 million of 5.25% Series mortgage bonds and $100 million of 4.70% Series mortgage bonds, each in December 2020, and the repayment of $200 million of 4.8% Series mortgage bonds in May 2021.

Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020

Other operation and maintenance expenses increased primarily due to:

•an increase of $11.2 million in nuclear generation expenses primarily due to higher nuclear labor costs and a higher scope of work performed in 2021 as compared to 2020;

•an increase of $8.7 million in compensation and benefits costs primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs;

•the effects of recording in second quarter 2020 final judgments to resolve claims in the Waterford 3 damages case against the DOE related to spent nuclear fuel storage costs. The damages awarded included the reimbursement of approximately $7.7 million of spent nuclear fuel storage costs previously recorded as other operation and maintenance expense. See Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation;

•an increase of $6.3 million in non-nuclear generation expenses due to higher expenses associated with plants placed in service, including the Lake Charles Power Station, which began commercial operation in March 2020, and the Washington Parish Energy Center, purchased in November 2020;

•an increase of $5.5 million in distribution operations expenses primarily due to higher distribution reliability costs and an increase in vegetation maintenance costs;

•an increase of $5.2 million in energy efficiency costs due to the timing of recovery from customers;

•a decrease of $4.2 million in nuclear insurance refunds; and

•several individually insignificant items.

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Taxes other than income taxes increased primarily due to increases in ad valorem taxes. Ad valorem taxes increased primarily due to higher assessments, including additions to plant in service.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Lake Charles Power Station, which was placed in service in March 2020, and the Washington Parish Energy Center, which was placed in service in November 2020.

Other regulatory charges (credits) - net includes regulatory charges of $29 million recorded in first quarter 2020 due to a settlement with the IRS related to the uncertain tax position regarding Hurricane Isaac Louisiana Act 55 financing because the savings will be shared with customers. See Note 3 in the Form 10-K for further discussion of the settlement and savings obligation.

Other income decreased primarily due to a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2020, including the Lake Charles Power Station project.

Interest expense increased primarily due to:

•the issuance of $350 million of 2.90% Series mortgage bonds in March 2020;

•the issuance of $1.1 billion of 0.62% Series mortgage bonds, $300 million of 2.90% Series mortgage bonds, and $300 million of 1.60% Series mortgage bonds, each in November 2020;

•the issuance of $500 million of 2.35% Series mortgage bonds and $500 million of 3.10% Series mortgage bonds, each in March 2021; and

•a decrease in the allowance for borrowed funds used during construction due to higher construction work in progress in 2020, including the Lake Charles Power Station project.

The increase was partially offset by the repayment of $200 million of 5.25% Series mortgage bonds and $100 million of 4.70% Series mortgage bonds, each in December 2020, and $200 million of 4.8% Series mortgage bonds in May 2021.

Income Taxes

The effective income tax rate was 15.4% for the second quarter 2021 and 17.1% for the six months ended June 30, 2021. The differences in the effective income tax rates for the second quarter 2021 and the six months ended June 30, 2021 versus the federal statutory rate of 21% were primarily due to book and tax differences related to the non-taxable income distributions earned on preferred membership interests, the amortization of excess accumulated deferred income taxes, and certain book and tax differences related to utility plant items, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was 17.4% for the second quarter 2020. The difference in the effective income tax rate for the second quarter 2020 versus the federal statutory rate of 21% was primarily due to book and tax differences related to the non-taxable income distributions earned on preferred membership interests, the amortization of excess accumulated deferred income taxes, and certain book and tax differences related to utility plant items, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was (4.1%) for the six months ended June 30, 2020. The difference in the effective income tax rate for the six months ended June 30, 2020 versus the federal statutory rate of 21% was primarily due to the settlement with the IRS on the treatment of funds received in conjunction with the Act 55 financing of Hurricane Isaac storm costs, permanent differences related to income tax deductions for stock-based

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compensation, book and tax differences related to the non-taxable income distributions earned on preferred membership interests, book and tax differences related to the allowance for equity funds used during construction, the amortization of excess accumulated deferred income taxes, and certain book and tax differences related to utility plant items, partially offset by state income taxes. See Note 10 to the financial statements herein for discussion of the IRS settlement. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 10 to the financial statements herein for discussion of the income tax deductions for stock-based compensation.

Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2021 and 2020 were as follows:

			2021						2020
			(In Thousands)
Cash and cash equivalents at beginning of period			$728,020						$2,006
Cash flow provided by (used in):
Operating activities			519,407						726,789
Investing activities			(1,836,723)						(732,085)
Financing activities			796,170						467,025
Net increase (decrease) in cash and cash equivalents			(521,146)						461,729
Cash and cash equivalents at end of period			$206,874						$463,735

Operating Activities

Net cash flow provided by operating activities decreased $207.4 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to:

•an increase of approximately $109.3 million in storm spending in 2021, primarily due to Hurricane Laura, Hurricane Delta, and Hurricane Zeta restoration efforts. See “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” above for discussion of storm restoration efforts;

•increased fuel costs as a result of Winter Storm Uri. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of fuel and purchased power cost recovery;

•an increase of $35.1 million in spending on nuclear refueling outages;

•income tax refunds of $20.7 million in 2020. Entergy Louisiana had income tax refunds in 2020 as a result of a refund of an overpayment on a prior year state income tax return; and

•an increase of $20.7 million in pension contributions in 2021. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding.

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Investing Activities

Net cash flow used in investing activities increased $1,104.6 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to:

•an increase of $921.6 million in storm spending in 2021, primarily due to Hurricane Laura, Hurricane Delta, and Hurricane Zeta restoration efforts. See “Hurricane Laura, Hurricane Delta, and Hurricane Zeta” above for discussion of storm restoration efforts;

•an increase of $74.4 million as a result of fluctuations in nuclear fuel activity, primarily due to variations from year to year in the timing and pricing of fuel reload requirements, materials and services deliveries, and the timing of cash payments during the nuclear fuel cycle;

•an increase of $73.7 million in distribution construction expenditures primarily due to investment in the reliability and infrastructure of Entergy Louisiana’s distribution system;

•$39.2 million in net receipts from storm reserve escrow accounts in 2020; and

•an increase of $28.1 million in nuclear construction expenditures primarily due to increased spending on various projects in 2021.

The increase was partially offset by a decrease of $55.4 million in non-nuclear generation construction expenditures due to higher spending in 2020 on the Lake Charles Power Station.

Financing Activities

Net cash flow provided by financing activities increased $329.1 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to:

•the issuance of $500 million of 2.35% Series mortgage bonds and $500 million of 3.10% Series mortgage bonds, each in March 2021, as compared to the issuances of $350 million of 2.90% Series mortgage bonds and $300 million of 4.20% Series mortgage bonds, each in March 2020;

•net long-term borrowings of $68.5 million in 2021 compared to net repayments of long-term borrowings of $59.9 million in 2020 on the nuclear fuel company variable interest entities’ credit facilities;

•money pool activity; and

•the payment of $16.5 million in common equity distributions in 2020 primarily to maintain Entergy Louisiana’s capital structure.

The decrease was partially offset by the repayment of $200 million of 4.80% Series mortgage bonds in May 2021 and the repayment of Entergy Louisiana Waterford VIE’s $40 million of 3.92% Series H secured notes in February 2021.

Decreases in Entergy Louisiana’s payable to the money pool are a use of cash flow, and Entergy Louisiana’s payable to the money pool decreased by $82.8 million for the six months ended June 30, 2020. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short term borrowings.

See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

Capital Structure

Entergy Louisiana’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio for Entergy Louisiana is primarily due to the issuance of $1 billion of mortgage bonds in March 2021.

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			June 30, 2021						December 31, 2020
Debt to capital			55.9		%				54.8		%
Effect of excluding securitization bonds			0.0		%				0.0		%
Debt to capital, excluding securitization bonds (a)			55.9		%				54.8		%
Effect of subtracting cash			(0.5		%)				(2.1		%)
Net debt to net capital, excluding securitization bonds (a)			55.4		%				52.7		%

(a)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 short-term borrowings, finance lease obligations, and long-term debt, including the currently maturing portion. Capital consists of debt and common equity. Net capital consists of capital less cash and cash equivalents. Entergy Louisiana uses the debt to capital ratios excluding securitization bonds in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy Louisiana’s financial condition because the securitization bonds are non-recourse to Entergy Louisiana, as more fully described in Note 5 to the financial statements in the Form 10-K. Entergy Louisiana also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Louisiana’s financial condition because net debt indicates Entergy Louisiana’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Louisiana’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.

Entergy Louisiana’s receivables from or (payables to) the money pool were as follows:

June 30,  2021						December 31, 2020						June 30, 2020						December 31, 2019
(In Thousands)
$103,651						$13,426						$87,635						($82,826)

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Entergy Louisiana has a credit facility in the amount of $350 million scheduled to expire in June 2026.  The credit facility includes fronting commitments for the issuance of letters of credit against $15 million of the borrowing capacity of the facility. As of June 30, 2021, there were no cash borrowings and no letters of credit outstanding under the credit facility.  In addition, Entergy Louisiana is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of June 30, 2021, $7.8 million in letters of credit were outstanding under Entergy Louisiana’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

The Entergy Louisiana nuclear fuel company variable interest entities have two separate credit facilities, each in the amount of $105 million and scheduled to expire in June 2024.  As of June 30, 2021, $64.6 million in loans were outstanding under the credit facility for the Entergy Louisiana River Bend nuclear fuel company variable interest entity. As of June 30, 2021, $62.1 million in loans were outstanding under the credit facility for the Entergy Louisiana Waterford nuclear fuel company variable interest entity. See Note 4 to the financial statements herein for additional discussion of the nuclear fuel company variable interest entity credit facilities.

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State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – State and Local Rate Regulation and Fuel Cost Recovery” in the Form 10-K for a discussion of state and local rate regulation and fuel cost recovery. The following are updates to that discussion.

Retail Rates - Electric

2017 Formula Rate Plan Filing

As discussed in the Form 10-K, in May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the J. Wayne Leonard Power Station (formerly St. Charles Power Station). In February 2021, LPSC staff filed testimony that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers. LPSC staff further recommended that the LPSC consider monitoring the remaining $3.1 million that was estimated to be incurred for completion of the project in the event the final costs exceed the estimated amounts. In July 2021 the LPSC approved a settlement between LPSC staff and Entergy Louisiana finding that substantially all the costs to construct J. Wayne Leonard Power Station were prudently incurred and eligible for recovery from customers.

Request for Extension and Modification of Formula Rate Plan

As discussed in the Form 10-K, in May 2020, Entergy Louisiana filed with the LPSC its application for authority to extend its formula rate plan. The parties reached a settlement in April 2021 regarding Entergy Louisiana’s proposed FRP extension. In May 2021 the LPSC approved the uncontested settlement. Key terms of the settlement include: a three year term (test years 2020, 2021, and 2022) covering a rate-effective period of September 2021 through August 2024; a 9.50% return on equity, with a smaller, 50 basis point deadband above and below (9.0%-10.0%); elimination of sharing if earnings are outside the deadband; a $63 million rate increase for test year 2020 (exclusive of riders); continuation of existing riders (transmission, additional capacity, etc.); addition of a distribution recovery mechanism permitting $225 million per year of distribution investment above a baseline level to be recovered dollar for dollar; modification of the tax mechanism to allow timely rate changes in the event the federal corporate income tax rate is changed from 21%; a cumulative rate increase limit of $70 million (exclusive of riders) for test years 2021 and 2022; and deferral of up to $7 million per year in 2021 and 2022 of expenditures on vegetation management for outside of right of way hazard trees.

2020 Formula Rate Plan Filing

    In June 2021, Entergy Louisiana filed its formula rate plan evaluation report for its 2020 calendar year operations. The 2020 test year evaluation report produced an earned return on common equity of 8.45%, with a base formula rate plan revenue increase of $63 million. Certain reductions in formula rate plan revenue driven by lower sales volumes, reductions in capacity cost and net MISO cost, and higher credits resulting from the Tax Cuts and Jobs Act offset the base formula rate plan revenue increase, leading to a net increase in formula rate plan revenue of $50.7 million. The report also included multiple new adjustments to account for, among other things, the calculation of distribution recovery mechanism revenues. The effects of the changes to total formula rate plan revenue are different for each legacy company, primarily due to differences in the legacy companies’ capacity cost changes, including the effect of true-ups. Legacy Entergy Louisiana formula rate plan revenues will increase by $27 million and legacy Entergy Gulf States Louisiana formula rate plan revenues will increase by $23.7 million. Subject to refund and LPSC review, the resulting changes will become effective for bills rendered during the first billing cycle of September 2021. Discovery is underway, and parties are required to file any objections to the formula rate plan revenue requirement by September 20, 2021. Entergy Louisiana’s response to any objections is due October 30, 2021. Should the parties be unable to resolve any objections, those issues will be set for hearing, with recovery of the associated costs subject to refund.

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Storm Cost Filings

In August 2020 and October 2020, Hurricane Laura, Hurricane Delta, and Hurricane Zeta caused significant damage to portions of Entergy Louisiana’s service area. The storms resulted in widespread outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the outages. Additionally, as a result of Hurricane Laura’s extensive damage to the grid infrastructure serving the impacted area, large portions of the underlying transmission system required nearly a complete rebuild.

In October 2020, Entergy Louisiana filed an application at the LPSC seeking approval of certain ratemaking adjustments to facilitate issuance of shorter-term bonds to provide interim financing for restoration costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta. Subsequently, Entergy Louisiana and the LPSC staff filed a joint motion seeking approval to exclude from the derivation of Entergy Louisiana’s capital structure and cost rate of debt for ratemaking purposes, including the allowance for funds used during construction, shorter-term debt up to $1.1 billion issued by Entergy Louisiana to fund costs associated with Hurricane Laura, Hurricane Delta, and Hurricane Zeta costs on an interim basis. In November 2020 the LPSC issued an order approving the joint motion, and Entergy Louisiana issued $1.1 billion of 0.62% Series mortgage bonds due November 2023. Also in November 2020, Entergy Louisiana drew $257 million from its funded storm reserves.

In February 2021, two winter storms (collectively, Winter Storm Uri) brought freezing rain and ice to Louisiana. Ice accumulation sagged or downed trees, limbs, and power lines, causing damage to Entergy Louisiana’s transmission and distribution systems. The additional weight of ice caused trees and limbs to fall into power lines and other electric equipment. When the ice melted, it affected vegetation and electrical equipment, causing incremental outages. As discussed above in “Fuel and purchased power recovery,” Entergy Louisiana is recovering the incremental fuel costs associated with Winter Storm Uri over a five-month period from April 2021 through August 2021.

In April 2021, Entergy Louisiana filed an application with the LPSC relating to Hurricane Laura, Hurricane Delta, Hurricane Zeta, and Winter Storm Uri restoration costs, and in July 2021, Entergy Louisiana made a supplemental filing updating the total restoration costs. Total restoration costs, as included in the July 2021 supplemental filing, for the repair and/or replacement of Entergy Louisiana’s electric facilities damaged by the storms are currently estimated to be approximately $2.06 billion, including approximately $1.68 billion in capital costs and approximately $380 million in non-capital costs. Including carrying costs through January 2022, Entergy Louisiana is seeking an LPSC determination that $2.11 billion was prudently incurred and, therefore, is eligible for recovery from customers. Additionally, Entergy Louisiana is requesting that the LPSC determine that re-establishment of a storm escrow account to the previously authorized amount of $290 million is appropriate. In June 2021 a procedural schedule was established with a hearing in January 2022. In July 2021, Entergy Louisiana supplemented the application with a request regarding the financing and recovery of the recoverable storm restoration costs. Specifically, Entergy Louisiana requested approval to securitize its restoration costs pursuant to Louisiana Act 55 financing, as supplemented by Act 293 of the Louisiana Legislature’s Regular Session of 2021. In total, Entergy Louisiana requested authorization for the issuance of system restoration bonds in one or more series in an aggregate principal amount of $2.18 billion, which includes the costs of re-establishing and funding a storm damage escrow account, carrying costs and unamortized debt costs on interim financing, and issuance costs.

Fuel and purchased power recovery

In February 2021, Entergy Louisiana incurred extraordinary fuel costs associated with the February 2021 winter storms. To mitigate the effect of these costs on customer bills, in March 2021 Entergy Louisiana requested and the LPSC approved the deferral and recovery of $166 million in incremental fuel costs over five months beginning in April 2021. The incremental fuel costs remain subject to review for reasonableness and eligibility for recovery through the fuel adjustment clause mechanism. The final amount of incremental fuel costs is subject to change through the MISO resettlement process. At its April 2021 meeting, the LPSC authorized its staff to review

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Entergy Louisiana, LLC and Subsidiaries

Management's Financial Discussion and Analysis

the prudence of February 2021 fuel costs incurred by all LPSC-jurisdictional utilities. At its June 2021 meeting, the LPSC approved the hiring of consultants to assist its staff in this review. Discovery is ongoing.

In March 2021 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings covering the period January 2018 through December 2020. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for that period. No audit report has been filed.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In addition, utilities may seek future recovery, subject to LPSC review and approval, of losses and expenses incurred due to compliance with the LPSC’s COVID-19 orders. The suspension of late fees and disconnects for non-payment was approved through the first billing cycle after July 16, 2020. In January 2021, Entergy Louisiana resumed disconnections for customers in all customer classes with past-due balances that have not made payment arrangements. Utilities seeking to recover the regulatory asset must formally petition the LPSC to do so, identifying the direct and indirect costs for which recovery is sought. Any such request is subject to LPSC review and approval. As of June 30, 2021, Entergy Louisiana recorded a regulatory asset of $54.7 million for costs associated with the COVID-19 pandemic.

Industrial and Commercial Customers

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Industrial and Commercial Customers” in the Form 10-K for a discussion of industrial and commercial customers.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation. 

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Nuclear Matters” in the Form 10-K for a discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy Louisiana’s accounting for nuclear decommissioning costs, utility regulatory accounting, impairment of long-lived assets, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2021 and 2020
(Unaudited)
						Three Months Ended												Six Months Ended
						2021						2020						2021						2020
						(In Thousands)												(In Thousands)
OPERATING REVENUES
Electric						$1,254,579						$1,001,601						$2,334,242						$1,914,142
Natural gas						13,019						10,051						41,000						28,157
TOTAL						1,267,598						1,011,652						2,375,242						1,942,299
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale						355,362						161,610						500,596						306,102
Purchased power						186,596						153,786						396,557						314,529
Nuclear refueling outage expenses						12,193						13,654						25,475						27,284
Other operation and maintenance						275,599						226,216						513,082						448,874
Decommissioning						17,035						16,203						33,858						32,204
Taxes other than income taxes						51,968						48,718						104,452						98,795
Depreciation and amortization						163,061						154,255						323,874						299,390
Other regulatory charges (credits) - net						(21,617)						(19,202)						9,480						(8,070)
TOTAL						1,040,197						755,240						1,907,374						1,519,108
OPERATING INCOME						227,401						256,412						467,868						423,191
OTHER INCOME
Allowance for equity funds used during construction						6,835						6,055						12,936						20,942
Interest and investment income						59,457						93,807						131,972						74,138
Miscellaneous - net						(36,033)						(66,811)						(70,671)						(17,210)
TOTAL						30,259						33,051						74,237						77,870
INTEREST EXPENSE
Interest expense						90,630						86,296						173,436						165,813
Allowance for borrowed funds used during construction						(3,068)						(3,202)						(5,827)						(10,334)
TOTAL						87,562						83,094						167,609						155,479
INCOME BEFORE INCOME TAXES						170,098						206,369						374,496						345,582
Income taxes						26,171						35,910						63,943						(14,273)
NET INCOME						$143,927						$170,459						$310,553						$359,855
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three and Six Months Ended June 30, 2021 and 2020
(Unaudited)
			Three Months Ended												Six Months Ended
			2021						2020						2021						2020
			(In Thousands)												(In Thousands)
Net Income			$143,927						$170,459						$310,553						$359,855
Other comprehensive income (loss)
Pension and other postretirement liabilities (net of tax expense (benefit) of $208, ($334), $64, and $3,006)			588						(945)						181						8,522
Other comprehensive income (loss)			588						(945)						181						8,522
Comprehensive Income			$144,515						$169,514						$310,734						$368,377
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2021 and 2020
(Unaudited)
						2021						2020
						(In Thousands)
OPERATING ACTIVITIES
Net income						$310,553						$359,855
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization						402,106						392,286
Deferred income taxes, investment tax credits, and non-current taxes accrued						90,537						(1,353)
Changes in working capital:
Receivables						(66,281)						(38,175)
Fuel inventory						(1,240)						(2,233)
Accounts payable						25,685						(37,576)
Prepaid taxes and taxes accrued						54,850						91,662
Interest accrued						2,162						3,689
Deferred fuel costs						(96,429)						(763)
Other working capital accounts						(36,605)						(13,069)
Changes in provisions for estimated losses						(291)						(38,621)
Changes in other regulatory assets						(124,939)						48,536
Changes in other regulatory liabilities						87,823						(42,203)
Changes in pension and other postretirement liabilities						(43,936)						(34,280)
Other						(84,588)						39,034
Net cash flow provided by operating activities						519,407						726,789
INVESTING ACTIVITIES
Construction expenditures						(1,655,993)						(690,049)
Allowance for equity funds used during construction						12,936						20,942
Payment for purchase of assets						—						(14,511)
Nuclear fuel purchases						(63,479)						(24,086)
Proceeds from the sale of nuclear fuel						—						35,041
Receipts from storm reserve escrow account						—						40,589
Payments to storm reserve escrow account						—						(1,398)
Changes to securitization account						(956)						755
Proceeds from nuclear decommissioning trust fund sales						459,326						223,736
Investment in nuclear decommissioning trust funds						(498,332)						(240,559)
Changes in money pool receivable - net						(90,225)						(87,635)
Litigation proceeds for reimbursement of spent nuclear fuel storage costs						—						5,090
Net cash flow used in investing activities						(1,836,723)						(732,085)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt						2,097,214						1,401,887
Retirement of long-term debt						(1,296,875)						(826,456)
Change in money pool payable - net						—						(82,826)
Distributions paid:
Common equity distributions paid						—						(16,500)
Other						(4,169)						(9,080)
Net cash flow provided by financing activities						796,170						467,025
Net increase (decrease) in cash and cash equivalents						(521,146)						461,729
Cash and cash equivalents at beginning of period						728,020						2,006
Cash and cash equivalents at end of period						$206,874						$463,735
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized						$165,480						$157,926
Income taxes						$—						($20,684)
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
June 30, 2021 and December 31, 2020
(Unaudited)
						2021						2020
						(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash						$231						$1,303
Temporary cash investments						206,643						726,717
Total cash and cash equivalents						206,874						728,020
Accounts receivable:
Customer						336,478						317,905
Allowance for doubtful accounts						(39,793)						(45,693)
Associated companies						191,251						81,624
Other						36,096						41,760
Accrued unbilled revenues						206,910						178,840
Total accounts receivable						730,942						574,436
Deferred fuel costs						98,679						2,250
Fuel inventory						51,920						50,680
Materials and supplies - at average cost						443,275						437,933
Deferred nuclear refueling outage costs						63,843						48,407
Prepayments and other						51,441						36,813
TOTAL						1,646,974						1,878,539
OTHER PROPERTY AND INVESTMENTS
Investment in affiliate preferred membership interests						1,390,587						1,390,587
Decommissioning trust funds						1,985,477						1,794,042
Non-utility property - at cost (less accumulated depreciation)						333,392						323,110
Other						13,500						13,399
TOTAL						3,722,956						3,521,138
UTILITY PLANT
Electric						26,204,300						25,619,789
Natural gas						271,712						262,744
Construction work in progress						577,975						667,281
Nuclear fuel						224,870						210,128
TOTAL UTILITY PLANT						27,278,857						26,759,942
Less - accumulated depreciation and amortization						9,610,279						9,372,224
UTILITY PLANT - NET						17,668,578						17,387,718
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $— as of June 30, 2021 and $5,088 as of December 31, 2020)						1,851,005						1,726,066
Deferred fuel costs						168,122						168,122
Other						33,094						23,924
TOTAL						2,052,221						1,918,112
TOTAL ASSETS						$25,090,729						$24,705,507
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
June 30, 2021 and December 31, 2020
(Unaudited)
						2021						2020
						(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt						$—						$240,000
Accounts payable:
Associated companies						116,333						103,148
Other						476,177						1,450,008
Customer deposits						151,053						152,612
Taxes accrued						97,467						42,617
Interest accrued						94,411						92,249
Current portion of unprotected excess accumulated deferred income taxes						31,138						31,138
Other						62,057						62,968
TOTAL						1,028,636						2,174,740
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued						2,230,734						2,138,522
Accumulated deferred investment tax credits						104,953						107,317
Regulatory liability for income taxes - net						425,192						447,628
Other regulatory liabilities						1,028,552						918,293
Decommissioning						1,612,748						1,573,307
Accumulated provisions						24,648						24,939
Pension and other postretirement liabilities						648,825						692,728
Long-term debt (includes securitization bonds of $—as of June 30, 2021 and $10,278 as of December 31, 2020)						9,836,133						8,787,451
Other						381,914						382,894
TOTAL						16,293,699						15,073,079
Commitments and Contingencies
EQUITY
Member's equity						7,763,886						7,453,361
Accumulated other comprehensive income						4,508						4,327
TOTAL						7,768,394						7,457,688
TOTAL LIABILITIES AND EQUITY						$25,090,729						$24,705,507
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Six Months Ended June 30, 2021 and 2020
(Unaudited)
			Common Equity
			Member’s Equity						Accumulated Other Comprehensive Income						Total
			(In Thousands)
Balance at December 31, 2019			$6,392,556						$4,562						$6,397,118
Net income			189,396						—						189,396
Other comprehensive income			—						9,467						9,467
Distributions declared on common equity			(11,500)						—						(11,500)
Other			(10)						—						(10)
Balance at March 31, 2020			6,570,442						14,029						6,584,471
Net income			170,459						—						170,459
Other comprehensive loss			—						(945)						(945)
Distributions declared on common equity			(5,000)						—						(5,000)
Other			(13)						—						(13)
Balance at June 30, 2020			$6,735,888						$13,084						$6,748,972
Balance at December 31, 2020			$7,453,361						$4,327						$7,457,688
Net income			166,626						—						166,626
Other comprehensive loss			—						(407)						(407)
Other			(16)						—						(16)
Balance at March 31, 2021			7,619,971						3,920						7,623,891
Net income			143,927						—						143,927
Other comprehensive income			—						588						588
Other			(12)						—						(12)
Balance at June 30, 2021			$7,763,886						$4,508						$7,768,394
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, LLC

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in Entergy Mississippi’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy Mississippi were approximately $65 million in February 2021 compared to approximately $35 million in February 2020. See Note 2 to the financial statements in the Form 10-K for discussion of storm cost recovery and fuel cost recovery at Entergy Mississippi.

In February 2021 the MPSC announced that it would launch a comprehensive review of the condition and resiliency of the state’s public utility infrastructure in response to the impacts of the February 2021 winter storms. Although the MPSC did not open a formal docket, the MPSC submitted data requests to Entergy Mississippi regarding the actions taken to ensure reliable operations of the electric network during the winter storm events and in anticipation of other future extreme weather events. In April 2021, Entergy Mississippi submitted responses to the MPSC data requests.

In April 2021 the MPSC opened a proceeding to investigate Entergy Mississippi’s membership in MISO. In the order, the MPSC noted the impact of the February 2021 winter storms, stating that it observed “excessive prices of natural gas and electricity” during the winter event. Entergy Mississippi submitted comments in the proceeding in June 2021.

Results of Operations

Net Income

Second Quarter 2021 Compared to Second Quarter 2020

Net income increased $12.5 million primarily due to higher retail electric price and higher volume/weather, partially offset by higher other operation and maintenance expenses, higher taxes other than income taxes, and higher depreciation and amortization expenses.

Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020

Net income increased $16 million primarily due to higher retail electric price and higher volume/weather, partially offset by higher other operation and maintenance expenses, higher depreciation and amortization expenses, and a higher effective income tax rate.

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Management's Financial Discussion and Analysis

Operating Revenues

Second Quarter 2021 Compared to Second Quarter 2020

Following is an analysis of the change in operating revenues comparing the second quarter 2021 to the second quarter 2020:

			Amount
			(In Millions)
2020 operating revenues			$298
Fuel, rider, and other revenues that do not significantly affect net income			37.9
Retail electric price			8.6
Volume/weather			4.5
2021 operating revenues			$349

Entergy Mississippi’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The retail electric price variance is primarily due to an interim increase in formula rate plan rates effective, in part, with the first billing cycle of April 2021. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan filings.

The volume/weather variance is primarily due to an increase of 73 GWh, or 3%, in billed electricity usage primarily due to an increase in commercial usage resulting from reduced impacts from the COVID-19 pandemic on businesses as compared to prior year. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Billed electric energy sales for Entergy Mississippi for the three months ended June 30, 2021 and 2020 are as follows:

			2021						2020						% Change
			(GWh)
Residential			1,095						1,117						(2)
Commercial			1,041						967						8
Industrial			576						562						2
Governmental			97						90						8
Total retail			2,809						2,736						3
Sales for resale:
Non-associated companies			1,643						1,039						58
Total			4,452						3,775						18

See Note 13 to the financial statements herein for additional discussion of Entergy Mississippi’s operating revenues.

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Entergy Mississippi, LLC

Management's Financial Discussion and Analysis

Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020

Following is an analysis of the change in operating revenues comparing the six months ended June 30, 2021 to the six months ended June 30, 2020:

			Amount
			(In Millions)
2020 operating revenues			$591.9
Fuel, rider, and other revenues that do not significantly affect net income			60.9
Retail electric price			20.9
Volume/weather			12.0
2021 operating revenues			$685.7

Entergy Mississippi’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The retail electric price variance is primarily due to increases in formula rate plan rates effective, in part, with the first billing cycles of April 2020 and April 2021 and the implementation of a vegetation management rider effective with the April 2020 billing cycle. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan filings and the vegetation management rider.

The volume/weather variance is primarily due to an increase of 286 GWh, or 5%, in billed electricity usage, including the effect of more favorable weather on residential sales and an increase in commercial usage.

Billed electric energy sales for Entergy Mississippi for the six months ended June 30, 2021 and 2020 are as follows:

			2021						2020						% Change
			(GWh)
Residential			2,590						2,367						9
Commercial			2,050						1,973						4
Industrial			1,096						1,118						(2)
Governmental			192						184						4
Total retail			5,928						5,642						5
Sales for resale:
Non-associated companies			3,096						1,866						66
Total			9,024						7,508						20

See Note 13 to the financial statements herein for additional discussion of Entergy Mississippi’s operating revenues.

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Management's Financial Discussion and Analysis

Other Income Statement Variances

Second Quarter 2021 Compared to Second Quarter 2020

Other operation and maintenance expenses increased primarily due to:

•an increase of $4.1 million in distribution operations expenses primarily due to higher distribution reliability costs and higher vegetation maintenance costs;

•an increase of $2 million in information technology costs due to higher contract costs and higher costs associated with system maintenance;

•an increase of $1.3 million in compensation and benefits costs primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs; and

•an increase of $1.1 million as a result of the amount of transmission costs allocated by MISO.

The increase was partially offset by a decrease of $2 million due to the timing of recovery of energy efficiency costs.

Taxes other than income taxes increased primarily due to increases in ad valorem taxes. Ad valorem taxes increased primarily due to higher assessments.

Depreciation and amortization expenses increased primarily as a result of additions to plant in service.

Other regulatory charges (credits) - net includes regulatory credits of $19.9 million, recorded in the second quarter 2021, to reflect the effects of the joint stipulation reached in the 2021 formula rate plan filing proceeding. See Note 2 to the financial statements herein for discussion of the 2021 formula rate plan filing.

Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020

Other operation and maintenance expenses increased primarily due to:

•an increase of $5.3 million in vegetation maintenance costs;

•an increase of $2.5 million as a result of the amount of transmission costs allocated by MISO;

•an increase of $1.8 million in compensation and benefits costs primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs; and

•several individually insignificant items.

The increase was partially offset by a decrease of $3.1 million due to the timing of recovery of energy efficiency costs.

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Entergy Mississippi, LLC

Management's Financial Discussion and Analysis

Depreciation and amortization expenses increased primarily as a result of additions to plant in service.

Taxes other than income taxes increased primarily due to increases in ad valorem taxes. Ad valorem taxes increased primarily due to higher assessments.

Other regulatory charges (credits) - net includes regulatory credits of $19.9 million, recorded in the second quarter 2021, to reflect the effects of the joint stipulation reached in the 2021 formula rate plan filing proceeding. See Note 2 to the financial statements herein for discussion of the 2021 formula rate plan filing.

Income Taxes

The effective income tax rate was 21.9% for the second quarter 2021 and 22% for the six months ended June 30, 2021. The differences in the effective income tax rates for the second quarter 2021 and the six months ended June 30, 2021 versus the federal statutory rate of 21% were primarily due to state income taxes, partially offset by certain book and tax differences related to utility plant items.

The effective income tax rate was 22.6% for the second quarter 2020. The difference in the effective income tax rate for the second quarter 2020 versus the federal statutory rate of 21% was primarily due to state income taxes, partially offset by certain book and tax differences related to utility plant items.

The effective income tax rate was 17.8% for the six months ended June 30, 2020. The difference in the effective income tax rate for the six months ended June 30, 2020 versus the federal statutory rate of 21% was primarily due to certain book and tax differences related to utility plant items and permanent differences related to income tax deductions for stock-based compensation, partially offset by state income taxes. See Note 3 to the financial statements in the Form 10-K for discussion of the income tax deductions for stock-based compensation.

Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2021 and 2020 were as follows:

			2021						2020
			(In Thousands)
Cash and cash equivalents at beginning of period			$18						$51,601
Cash flow provided by (used in):
Operating activities			121,636						112,422
Investing activities			(323,460)						(261,597)
Financing activities			201,817						167,758
Net increase (decrease) in cash and cash equivalents			(7)						18,583
Cash and cash equivalents at end of period			$11						$70,184

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Management's Financial Discussion and Analysis

Operating Activities

Net cash flow provided by operating activities increased $9.2 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to the timing of payments to vendors. The increase was partially offset by increased fuel costs as a result of Winter Storm Uri, the timing of collections of receivables from customers, in part due to the COVID-19 pandemic, and an increase of approximately $14.1 million in storm spending in 2021, primarily due to Winter Storm Uri. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred. See Note 2 to the financial statements in the Form 10-K for a discussion of fuel and purchased power cost recovery.

Investing Activities

Net cash flow used in investing activities increased $61.9 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to:

•an increase of $86.2 million in distribution construction expenditures primarily due to increased spending on the reliability and infrastructure of Entergy Mississippi’s distribution system and storm spending in 2021; and

•money pool activity.

The increase was partially offset by $24.6 million in plant upgrades for Choctaw Generating Station in March 2020.

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 by $31.4 million for the six months ended June 30, 2020. The money pool is an inter-company borrowing arrangement designed to reduce the Utility’s subsidiaries’ need for external short-term borrowings.

Financing Activities

Net cash flow provided by financing activities increased $34.1 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to the issuance of $200 million of 3.50% Series mortgage bonds in March 2021, partially offset by the issuance of $170 million of 3.50% Series mortgage bonds in May 2020. See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

Capital Structure

Entergy Mississippi’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio for Entergy Mississippi is primarily due to the issuance of $200 million of mortgage bonds in March 2021.

			June 30,  2021						December 31, 2020
Debt to capital			53.2		%				51.7		%
Effect of subtracting cash			—		%				—		%
Net debt to net capital			53.2		%				51.7		%

Net debt consists of debt less cash and cash equivalents.  Debt consists of short-term borrowings, finance 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 debt to 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.  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

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evaluating Entergy Mississippi’s financial condition because net debt indicates Entergy Mississippi’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Mississippi’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.

Entergy Mississippi’s receivables from or (payables to) the money pool were as follows:

June 30,  2021						December 31, 2020						June 30,  2020						December 31, 2019
(In Thousands)
($16,998)						($16,516)						$13,311						$44,693

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Entergy Mississippi has three separate credit facilities in the aggregate amount of $82.5 million scheduled to expire in April 2022. No borrowings were outstanding under the credit facilities as of June 30, 2021.  In addition, Entergy Mississippi is a party to an uncommitted letter of credit facility primarily as a means to post collateral to support its obligations to MISO. As of June 30, 2021, $2 million of MISO letters of credit and $7.9 million of non-MISO letters of credit were outstanding under this facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

Entergy Mississippi has $33 million in its storm reserve escrow account at June 30, 2021.

State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - State and Local Rate Regulation and Fuel-Cost Recovery” in the Form 10-K for a discussion of the formula rate plan and fuel and purchased power cost recovery. The following are updates to that discussion.

2021 Formula Rate Plan Filing

In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2021 test year filing shows a $95.4 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, is capped at 4% of retail revenues, which equates to a revenue change of $44.3 million. The 2021 evaluation report also includes $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs are not subject to the 4% cap and result in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compares actual 2020 results to the approved benchmark return on rate base and reflects the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing includes an interim capacity adjustment true-up for the Choctaw Generating Station, which increases the look-back interim rate adjustment by $1.7 million. These interim rate adjustments total $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which are not subject to the 2% cap

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Management's Financial Discussion and Analysis

of 2020 retail revenues, were included in the April 2021 rate adjustments.

In June 2021, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2021 test year filing that resulted in a total rate increase of $48.2 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2020 look-back filing reflected an earned return on rate base of 6.12% in calendar year 2020, which is below the look-back bandwidth, resulting in a $17.5 million increase in formula rate plan revenues on an interim basis through May 2021. This includes $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. See “COVID-19 Orders” below for additional discussion of provisions of the joint stipulation related to COVID-19 expenses. In June 2021 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2021. In June 2021, Entergy Mississippi recorded regulatory assets of $19.9 million to reflect the effects of the joint stipulation.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the MPSC issued an order authorizing utilities to defer incremental costs and expenses associated with COVID-19 pandemic compliance and to seek future recovery through rates of the prudently incurred incremental costs and expenses. In December 2020, Entergy Mississippi resumed disconnections for commercial, industrial, and governmental customers with past-due balances that have not made payment arrangements. In January 2021, Entergy Mississippi resumed disconnecting service for residential customers with past-due balances that have not made payment arrangements. Pursuant to the June 2021 MPSC order approving Entergy Mississippi’s 2021 formula rate plan filing, Entergy Mississippi stopped deferring COVID-19 non-bad debt expenses effective December 31, 2020 and will include those expenses in the look-back filing for the 2021 formula rate plan test year. In the order, the MPSC also adopted Entergy Mississippi’s quantification and methodology for calculating COVID-19 incremental bad debt expenses and authorized Entergy Mississippi to continue deferring these bad debt expenses through December 2021. As of June 30, 2021, Entergy Mississippi recorded a regulatory asset of $19.3 million for costs associated with the COVID-19 pandemic.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation. 

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Nuclear Matters” in the Form 10-K for a discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy Mississippi’s accounting for utility regulatory accounting, impairment of long-lived assets, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

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Management's Financial Discussion and Analysis

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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ENTERGY MISSISSIPPI, LLC
INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2021 and 2020
(Unaudited)
						Three Months Ended												Six Months Ended
						2021						2020						2021						2020
						(In Thousands)												(In Thousands)
OPERATING REVENUES
Electric						$349,040						$297,954						$685,659						$591,876
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale						65,613						38,730						125,810						102,027
Purchased power						63,892						56,679						132,483						109,322
Other operation and maintenance						73,899						66,343						141,730						128,680
Taxes other than income taxes						27,076						22,697						52,975						49,887
Depreciation and amortization						56,158						52,296						111,194						103,451
Other regulatory charges (credits) - net						(21,630)						(6,496)						(13,501)						(10,377)
TOTAL						265,008						230,249						550,691						482,990
OPERATING INCOME						84,032						67,705						134,968						108,886
OTHER DEDUCTIONS
Allowance for equity funds used during construction						2,029						1,588						3,697						3,027
Interest and investment income						7						135						49						255
Miscellaneous - net						(2,205)						(2,589)						(4,518)						(4,885)
TOTAL						(169)						(866)						(772)						(1,603)
INTEREST EXPENSE
Interest expense						18,922						17,192						36,535						33,775
Allowance for borrowed funds used during construction						(852)						(634)						(1,529)						(1,185)
TOTAL						18,070						16,558						35,006						32,590
INCOME BEFORE INCOME TAXES						65,793						50,281						99,190						74,693
Income taxes						14,377						11,388						21,802						13,274
NET INCOME						$51,416						$38,893						$77,388						$61,419
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, LLC
STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2021 and 2020
(Unaudited)
						2021						2020
						(In Thousands)
OPERATING ACTIVITIES
Net income						$77,388						$61,419
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization						111,194						103,451
Deferred income taxes, investment tax credits, and non-current taxes accrued						33,499						13,126
Changes in assets and liabilities:
Receivables						(9,164)						7,076
Fuel inventory						954						(5,747)
Accounts payable						38,287						9,943
Taxes accrued						(49,438)						(34,195)
Interest accrued						(4,623)						1,399
Deferred fuel costs						(46,714)						(2,840)
Other working capital accounts						(27,684)						135
Provisions for estimated losses						(7,860)						(1,782)
Other regulatory assets						(13,050)						(28,290)
Other regulatory liabilities						13,520						(11,548)
Pension and other postretirement liabilities						(10,086)						(5,353)
Other assets and liabilities						15,413						5,628
Net cash flow provided by operating activities						121,636						112,422
INVESTING ACTIVITIES
Construction expenditures						(327,163)						(267,231)
Allowance for equity funds used during construction						3,697						3,027
Changes in money pool receivable - net						—						31,382
Payment for the purchase of plant or assets						—						(28,612)
Other						6						(163)
Net cash flow used in investing activities						(323,460)						(261,597)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt						200,543						165,408
Changes in money pool payable - net						482						—
Common equity distributions paid						—						(2,500)
Other						792						4,850
Net cash flow provided by financing activities						201,817						167,758
Net increase (decrease) in cash and cash equivalents						(7)						18,583
Cash and cash equivalents at beginning of period						18						51,601
Cash and cash equivalents at end of period						$11						$70,184
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized						$39,925						$31,196
Income taxes						($8,045)						$—
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, LLC
BALANCE SHEETS
ASSETS
June 30, 2021 and December 31, 2020
(Unaudited)
						2021						2020
						(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash						$11						$11
Temporary cash investments						—						7
Total cash and cash equivalents						11						18
Accounts receivable:
Customer						91,479						105,732
Allowance for doubtful accounts						(13,646)						(19,527)
Associated companies						4,226						2,740
Other						15,985						11,821
Accrued unbilled revenues						71,400						59,514
Total accounts receivable						169,444						160,280
Deferred fuel costs						32,023						—
Fuel inventory - at average cost						16,163						17,117
Materials and supplies - at average cost						65,915						59,542
Prepayments and other						22,447						4,876
TOTAL						306,003						241,833
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)						4,535						4,543
Escrow accounts						48,932						64,635
TOTAL						53,467						69,178
UTILITY PLANT
Electric						6,275,518						6,084,730
Construction work in progress						172,783						134,854
TOTAL UTILITY PLANT						6,448,301						6,219,584
Less - accumulated depreciation and amortization						2,068,644						2,005,087
UTILITY PLANT - NET						4,379,657						4,214,497
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets						480,391						467,341
Other						16,239						14,413
TOTAL						496,630						481,754
TOTAL ASSETS						$5,235,757						$5,007,262
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, LLC
BALANCE SHEETS
LIABILITIES AND EQUITY
June 30, 2021 and December 31, 2020
(Unaudited)
						2021						2020
						(In Thousands)
CURRENT LIABILITIES
Accounts payable:
Associated companies						$64,309						$61,727
Other						118,387						117,629
Customer deposits						86,028						86,200
Taxes accrued						58,646						108,084
Interest accrued						16,266						20,889
Deferred fuel costs						—						14,691
Other						23,075						34,270
TOTAL						366,711						443,490
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued						680,901						646,674
Accumulated deferred investment tax credits						11,025						9,062
Regulatory liability for income taxes - net						219,343						224,000
Other regulatory liabilities						34,005						15,828
Asset retirement cost liabilities						10,035						9,762
Accumulated provisions						38,644						46,504
Pension and other postretirement liabilities						100,700						110,901
Long-term debt						1,981,674						1,780,577
Other						42,597						47,730
TOTAL						3,118,924						2,891,038
Commitments and Contingencies
EQUITY
Member's equity						1,750,122						1,672,734
TOTAL						1,750,122						1,672,734
TOTAL LIABILITIES AND EQUITY						$5,235,757						$5,007,262
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, LLC
STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Six Months Ended June 30, 2021 and 2020
(Unaudited)
						Member's Equity
						(In Thousands)
Balance at December 31, 2019						$1,542,151
Net income						22,526
Common equity distributions						(2,500)
Balance at March 31, 2020						1,562,177
Net income						38,893
Balance at June 30, 2020						$1,601,070
Balance at December 31, 2020						$1,672,734
Net income						25,972
Balance at March 31, 2021						1,698,706
Net income						51,416
Balance at June 30, 2021						$1,750,122
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Hurricane Zeta

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Zeta” in the Form 10-K for a discussion of Hurricane Zeta, which caused significant damage to Entergy New Orleans’s service area. In March 2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. See Note 2 to the financial statements herein for discussion of the storm cost certification filing made in 2021 by Entergy New Orleans.

Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy New Orleans’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy New Orleans were approximately $35 million in February 2021 compared to approximately $25 million in February 2020. See Note 2 to the financial statements in the Form 10-K for discussion of fuel cost recovery at Entergy New Orleans. See “Load Shed Investigation” below for discussion of the investigation initiated by the City Council in February 2021.

Results of Operations

Net Income

Second Quarter 2021 Compared to Second Quarter 2020

Net income remained relatively unchanged, decreasing by $0.3 million, primarily due to higher other operation and maintenance expenses, partially offset by higher volume/weather and higher retail electric price.

Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020

Net income decreased $9.7 million primarily due to higher other operation and maintenance expenses and higher depreciation and amortization expenses, partially offset by higher retail electric price and higher volume/weather.

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Entergy New Orleans, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Operating Revenues

Second Quarter 2021 Compared to Second Quarter 2020

Following is an analysis of the change in operating revenues comparing second quarter 2021 to second quarter 2020:

			Amount
			(In Millions)
2020 operating revenues			$147.3
Fuel, rider, and other revenues that do not significantly affect net income			20.3
Volume/weather			6.8
Retail electric price			4.3
2021 operating revenues			$178.7

Entergy New Orleans’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The volume/weather variance is primarily due to an increase of 30 GWh, or 2%, in billed electricity usage, including increased commercial usage resulting from reduced impacts from the COVID-19 pandemic on businesses as compared to prior year, partially offset by the effect of less favorable weather on commercial and residential sales. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

The retail electric price variance is primarily due to an interim increase in formula rate plan revenues resulting from the recovery of New Orleans Power Station costs, effective November 2020. See Note 2 to the financial statements in the Form 10-K for further discussion of the rate case resolution.

Billed electric energy sales for Entergy New Orleans for the three months ended June 30, 2021 and 2020 are as follows:

			2021						2020						% Change
			(GWh)
Residential			492						520						(5)
Commercial			484						440						10
Industrial			108						106						2
Governmental			189						177						7
Total retail			1,273						1,243						2
Sales for resale:
Non-associated companies			530						473						12
Total			1,803						1,716						5

See Note 13 to the financial statements herein for additional discussion of Entergy New Orleans’s operating revenues.

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Management's Financial Discussion and Analysis

Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020

Following is an analysis of the change in operating revenues comparing the six months ended June 30, 2021 to the six months ended June 30, 2020:

			Amount
			(In Millions)
2020 operating revenues			$296.6
Fuel, rider, and other revenues that do not significantly affect net income			25.6
Retail electric price			19.6
Volume/weather			6.3
2021 operating revenues			$348.1

Entergy New Orleans’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The retail electric price variance is primarily due to an interim increase in formula rate plan revenues resulting from the recovery of New Orleans Power Station costs, effective November 2020. See Note 2 to the financial statements in the Form 10-K for further discussion of the rate case resolution.

The volume/weather variance is primarily due to an increase of 55 GWh, or 2%, in billed electricity usage, including the effect of more favorable weather on residential sales, partially offset by lower volume in the residential and industrial sectors.

Billed electric energy sales for Entergy New Orleans for the six months ended June 30, 2021 and 2020 are as follows:

			2021						2020						% Change
			(GWh)
Residential			1,087						1,021						6
Commercial			933						936						—
Industrial			200						208						(4)
Governmental			361						361						—
Total retail			2,581						2,526						2
Sales for resale:
Non-associated companies			619						1,074						(42)
Total			3,200						3,600						(11)

See Note 13 to the financial statements herein for additional discussion of Entergy New Orleans’s operating revenues.

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Management's Financial Discussion and Analysis

Other Income Statement Variances

Second Quarter 2021 Compared to Second Quarter 2020

Other operation and maintenance expenses increased primarily due to:

•an increase of $3.2 million due to an increase in bad debt expense resulting from the COVID-19 pandemic. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of regulatory activity associated with the COVID-19 pandemic;

•an increase of $2.1 million in non-nuclear generation expenses primarily due to the timing of the scope of work performed during plant outages as compared to the same period in 2020 and the New Orleans Power Station, which was placed in service in May 2020;

•an increase of $1.8 million in distribution expenses primarily due to higher distribution reliability and higher vegetation maintenance costs; and

•an increase of $1.7 million in energy efficiency costs.

Other income decreased primarily due to a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2020, including the New Orleans Power Station and New Orleans Solar Station projects.

Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020

Other operation and maintenance expenses increased primarily due to:

•an increase of $5.6 million in non-nuclear generation expenses primarily due to the timing of the scope of work performed during plant outages as compared to the same period in 2020 and the New Orleans Power Station, which was placed in service in May 2020;

•an increase of $5.3 million in energy efficiency costs;

•an increase of $3.8 million due to an increase in bad debt expense resulting from the COVID-19 pandemic. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of regulatory activity associated with the COVID-19 pandemic; and

•an increase of $3.1 million in distribution expenses primarily due to higher distribution reliability and higher vegetation maintenance costs.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the New Orleans Power Station, which was placed in service in May 2020.

Other regulatory charges (credits) - net includes regulatory credits recorded in first quarter 2020 to reflect compliance with terms of the 2018 combined rate case resolution approved by the City Council in February 2020. See Note 2 to the financial statements in the Form 10-K for discussion of the rate case resolution.

Other income decreased primarily due to a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2020, including the New Orleans Power Station and New Orleans Solar Station projects.

Income Taxes

The effective income tax rate was 28% for second quarter 2021 and 29.8% for the six months ended June 30, 2021. The difference in the effective income tax rates for second quarter 2021 and the six months ended June 30, 2021 versus the federal statutory rate of 21% were primarily due to state income taxes and the provision for uncertain tax positions, partially offset by certain book and tax differences related to utility plant items.

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Management's Financial Discussion and Analysis

The effective income tax rate was (53.5%) for second quarter 2020. The difference in the effective income tax rate for second quarter 2020 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, certain book and tax differences related to utility plant items, and book and tax differences related to the allowance for equity funds used during construction, partially offset by state income taxes and the provision for uncertain tax positions. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was (38.2%) for the six months ended June 30, 2020. The difference in the effective income tax rate for the six months ended June 30, 2020 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, certain book and tax differences related to utility plant items, book and tax differences related to the allowance for equity funds used during construction, and permanent differences related to income tax deductions for stock-based compensation, partially offset by the provision for uncertain tax positions and state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 10 to the financial statements herein for discussion of the income tax deductions for stock-based compensation.

Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2021 and 2020 were as follows:

			2021						2020
			(In Thousands)
Cash and cash equivalents at beginning of period			$26						$6,017
Cash flow provided by (used in):
Operating activities			27,188						24,660
Investing activities			(48,660)						(112,552)
Financing activities			21,472						112,620
Net increase in cash and cash equivalents			—						24,728
Cash and cash equivalents at end of period			$26						$30,745

Operating Activities

Net cash flow provided by operating activities increased $2.5 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to the timing of collection of receivables from customers and payments to vendors and income tax payments of $0.3 million in 2021 compared to income tax payments of $3.3 million in 2020. Entergy New Orleans made income tax payments in 2020 in accordance with an intercompany tax allocation agreement.

The increase was partially offset by:

•an increase of $5.1 million in storm spending in 2021, primarily due to Hurricane Zeta restoration efforts. See “Hurricane Zeta” above for discussion of hurricane restoration efforts; and

•an increase of $2.1 million in pension contributions in 2021. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding.

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Investing Activities

Net cash flows used in investing activities decreased $63.9 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to:

•$44.2 million in receipts from storm reserve escrow accounts in 2021;

•a decrease of $32.2 million in non-nuclear generation construction expenditures primarily due to lower spending in 2021 on the New Orleans Power Station and the New Orleans Solar Station projects; and

•a decrease of $7.9 million in distribution construction expenditures primarily due to lower spending in 2021 on advanced metering infrastructure.

The decrease in distribution construction expenditures was partially offset by an increase of $14.4 million in storm spending in 2021. See “Hurricane Zeta” above for discussion of hurricane restoration efforts.

Financing Activities

Net cash flow provided by financing activities decreased $91.1 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to the issuance of $78 million of 3.00% Series mortgage bonds and the issuance of $62 million of 3.75% Series mortgage bonds, each in March 2020. The decrease was partially offset by money pool activity and $20 million in repayments on long-term credit borrowings in 2020.

Increases in Entergy New Orleans’s payable to the money pool are a source of cash flow, and Entergy New Orleans’s payable to the money pool increased $27.7 million for the six months ended June 30, 2021. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

Capital Structure

Entergy New Orleans’s debt to capital ratio is shown in the following table.

			June 30, 2021						December 31, 2020
Debt to capital			51.5		%				51.5		%
Effect of excluding securitization bonds			(1.8		%)				(1.6		%)
Debt to capital, excluding securitization bonds (a)			49.7		%				49.9		%
Effect of subtracting cash			—		%				—		%
Net debt to net capital, excluding securitization bonds (a)			49.7		%				49.9		%

(a)Calculation excludes the securitization bonds, which are non-recourse to Entergy New Orleans.

Net debt consists of debt less cash and cash equivalents. Debt consists of short-term borrowings, finance lease obligations, long-term debt, including the currently maturing portion, and the long-term payable due to an associated company. Capital consists of debt and equity. Net capital consists of capital less cash and cash equivalents. Entergy New Orleans uses the debt to capital ratios excluding securitization bonds in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy New Orleans’s financial condition because the securitization bonds are non-recourse to Entergy New Orleans, as more fully described in Note 5 to the financial statements in the Form 10-K. Entergy New Orleans also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides

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useful information to its investors and creditors in evaluating Entergy New Orleans’s financial condition because net debt indicates Entergy New Orleans’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy New Orleans’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.  

Entergy New Orleans’s receivables from or (payables to) the money pool were as follows:

June 30, 2021						December 31, 2020						June 30, 2020						December 31, 2019
(In Thousands)
($37,874)						($10,190)						$5,777						$5,191

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Entergy New Orleans has a credit facility in the amount of $25 million scheduled to expire in June 2024. The credit facility includes fronting commitments for the issuance of letters of credit against $10 million of the borrowing capacity of the facility. As of June 30, 2021, there were no cash borrowings and no letters of credit outstanding under the facility. In addition, Entergy New Orleans is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of June 30, 2021, a $1 million letter of credit was outstanding under Entergy New Orleans’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

Entergy New Orleans has $38.8 million in its storm reserve escrow account at June 30, 2021.

State and Local Rate Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – State and Local Rate Regulation” in the Form 10-K for a discussion of state and local rate regulation. The following are updates to that discussion.

Retail Rates

2021 Formula Rate Plan Filing

In July 2021, Entergy New Orleans submitted to the City Council its formula rate plan 2020 test year filing. The 2020 test year evaluation report produced an earned return on equity of 6.26% compared to the authorized return on equity of 9.35%. Entergy New Orleans seeks approval of a $64 million rate increase based on the formula set by the City Council in the 2018 rate case. The formula results in an increase in authorized electric revenues of $40 million and an increase in authorized gas revenues of $18.8 million. Entergy New Orleans also seeks to commence collecting $5.2 million in electric revenues and $0.3 million in gas revenues that were previously approved by the City Council for collection through the formula rate plan. The filing is subject to review by the City Council and other parties over a 75-day review period, followed by a 25-day period to resolve any disputes among the parties. Resulting rates will be effective with the first billing cycle of November 2021 pursuant to the formula rate plan tariff. For any disputed rate adjustments, however, the City Council would set a litigated procedural schedule that would extend the process for City Council approval of disputed rate adjustments into 2022.

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COVID-19 Orders

As discussed in the Form 10-K, in June 2020 the City Council established the City Council Cares Program and directed Entergy New Orleans to use the approximately $7 million refund received from the Entergy Arkansas opportunity sales FERC proceeding and approximately $15 million of non-securitized storm reserves to fund this program, which was intended to provide temporary bill relief to customers who became unemployed during the COVID-19 pandemic. The program became effective July 1, 2020 and offered qualifying residential customers bill credits of $100 per month for up to four months, for a maximum of $400 in residential customer bill credits. As of June 30, 2021, the program expired and credits of $4.3 million have been applied to customer bills under the City Council Cares Program.

Additionally, as discussed in the Form 10-K, in February 2021 the City Council adopted a resolution suspending residential customer disconnections for non-payment of utility bills and suspending the assessment and accumulation of late fees on residential customers with past-due balances through May 15, 2021, which was not extended by the City Council. As of June 30, 2021, Entergy New Orleans recorded a regulatory asset of $13.8 million for costs associated with the COVID-19 pandemic.

Hurricane Zeta

In October 2020, Hurricane Zeta caused significant damage to Entergy New Orleans’s service area. The storm resulted in widespread power outages, significant damage to distribution and transmission infrastructure, and the loss of sales during the power outages. In March 2021, Entergy New Orleans withdrew $44 million from its funded storm reserves. In May 2021, Entergy New Orleans filed an application with the City Council requesting approval and certification that its system restoration costs associated with Hurricane Zeta of approximately $36 million, including approximately $28 million in capital costs and approximately $8 million in non-capital costs, were reasonable and necessary to enable Entergy New Orleans to restore electric service to its customers and Entergy New Orleans’s electric utility infrastructure. Additionally, Entergy New Orleans plans to make a separate filing at an appropriate time to the City Council requesting replenishment of its storm reserves.

Renewable Portfolio Standard Rulemaking

As discussed in the Form 10-K, in March 2019 the City Council initiated a rulemaking proceeding to consider whether to establish a renewable portfolio standard. The rulemaking considered, among other issues, whether to adopt a renewable portfolio standard, whether such standard should be voluntary or mandatory, what kinds of technologies should qualify for inclusion in the rules, what level, if any, of renewable generation should be required, and whether penalties are an appropriate component of the proposed rules. In August 2020 the City Council advisors issued a final draft of the rules for review and comment from the parties before final rules are proposed for consideration by the City Council. Entergy New Orleans filed comments in September and October 2020. In February 2021 the City Council amended the proposed draft rules to exclude beneficial electrification and carbon capture from the technologies eligible for credit under the Renewable and Clean Portfolio Standard and opened a 30-day comment period regarding the proposed amendments. Under the rule, however, these technologies can be approved by the City Council as a “qualified measure” on a case-by-case basis. The City Council approved the draft rule, as amended, in May 2021.

Load Shed Investigation

On February 16, 2021, due to high customer demand and limited generation, MISO issued an order requiring load-serving entities throughout its southern region to shed load to protect the integrity of the bulk electric system. Entergy New Orleans was required to shed load of at least 26 MW, but due to certain complications with its automated load shed program and certain load measurement issues, it inadvertently shed approximately 105 MW of load in its service area. The maximum time any customer was without power due to the load shed event was one hour and forty minutes. In late February 2021 the City Council ordered its advisors to conduct an investigation into

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the load shed event and to issue a report, which was completed and filed in April 2021. The report recommended that the City Council open an additional docket to determine whether any of Entergy New Orleans’s actions were imprudent. In May 2021 the City Council opened a docket directing its advisors to conduct a prudence investigation and determine whether financial and/or other penalties should be imposed by the City Council. In June 2021, Entergy New Orleans filed a response to the show cause docket that outlined how its response to Winter Storm Uri was reasonable under the circumstances. A City Council decision is expected in the fourth quarter 2021 based on the procedural schedule in the show cause docket. Entergy New Orleans would oppose any attempt to levy a fine under the circumstances presented.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation. 

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Nuclear Matters” in the Form 10-K for further discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy New Orleans’s accounting for utility regulatory accounting, impairment of long-lived assets, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2021 and 2020
(Unaudited)
						Three Months Ended												Six Months Ended
						2021						2020						2021						2020
						(In Thousands)												(In Thousands)
OPERATING REVENUES
Electric						$159,761						$134,899						$298,909						$258,330
Natural gas						18,979						12,444						49,166						38,315
TOTAL						178,740						147,343						348,075						296,645
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale						34,510						16,836						53,522						44,331
Purchased power						57,177						57,985						125,847						114,452
Other operation and maintenance						40,977						29,126						79,155						59,830
Taxes other than income taxes						12,294						15,642						24,850						28,848
Depreciation and amortization						18,153						15,626						36,314						30,701
Other regulatory charges (credits) - net						2,575						4,526						5,705						(1,210)
TOTAL						165,686						139,741						325,393						276,952
OPERATING INCOME						13,054						7,602						22,682						19,693
OTHER INCOME
Allowance for equity funds used during construction						376						2,048						634						4,533
Interest and investment income						5						43						14						96
Miscellaneous - net						(204)						168						(506)						(570)
TOTAL						177						2,259						142						4,059
INTEREST EXPENSE
Interest expense						6,962						7,635						13,991						14,275
Allowance for borrowed funds used during construction						(167)						(985)						(283)						(2,180)
TOTAL						6,795						6,650						13,708						12,095
INCOME BEFORE INCOME TAXES						6,436						3,211						9,116						11,657
Income taxes						1,805						(1,718)						2,714						(4,458)
NET INCOME						$4,631						$4,929						$6,402						$16,115
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2021 and 2020
(Unaudited)
						2021						2020
						(In Thousands)
OPERATING ACTIVITIES
Net income						$6,402						$16,115
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization						36,314						30,701
Deferred income taxes, investment tax credits, and non-current taxes accrued						4,907						1,228
Changes in assets and liabilities:
Receivables						(15,306)						5,255
Fuel inventory						725						1,042
Accounts payable						(7,309)						(1,725)
Taxes accrued						948						1,887
Interest accrued						(1,315)						529
Deferred fuel costs						4,423						3,351
Other working capital accounts						(11,944)						(19,793)
Provisions for estimated losses						(40,152)						1,521
Other regulatory assets						35,038						3,508
Other regulatory liabilities						4,823						(14,151)
Pension and other postretirement liabilities						(7,352)						(7,523)
Other assets and liabilities						16,986						2,715
Net cash flow provided by operating activities						27,188						24,660
INVESTING ACTIVITIES
Construction expenditures						(94,173)						(114,961)
Allowance for equity funds used during construction						634						4,533
Payment for purchase of assets						—						(1,584)
Changes in money pool receivable - net						—						(586)
Receipts from storm reserve escrow account						44,200						—
Payments to storm reserve escrow account						(7)						(405)
Changes in securitization account						686						451
Net cash flow used in investing activities						(48,660)						(112,552)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt						—						138,939
Retirement of long-term debt						(5,749)						(25,616)
Change in money pool payable - net						27,684						—
Other						(463)						(703)
Net cash flow provided by financing activities						21,472						112,620
Net increase in cash and cash equivalents						—						24,728
Cash and cash equivalents at beginning of period						26						6,017
Cash and cash equivalents at end of period						$26						$30,745
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized						$14,684						$13,132
Income taxes						$324						$3,332
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
June 30, 2021 and December 31, 2020
(Unaudited)
						2021						2020
						(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash						$26						$26
Total cash and cash equivalents						26						26
Securitization recovery trust account						2,678						3,364
Accounts receivable:
Customer						86,901						70,694
Allowance for doubtful accounts						(21,132)						(17,430)
Associated companies						1,406						2,381
Other						8,944						4,248
Accrued unbilled revenues						30,149						31,069
Total accounts receivable						106,268						90,962
Deferred fuel costs						—						2,130
Fuel inventory - at average cost						1,253						1,978
Materials and supplies - at average cost						16,034						16,550
Prepayments and other						16,257						3,715
TOTAL						142,516						118,725
OTHER PROPERTY AND INVESTMENTS
Non-utility property at cost (less accumulated depreciation)						1,016						1,016
Storm reserve escrow account						38,846						83,038
TOTAL						39,862						84,054
UTILITY PLANT
Electric						1,825,128						1,821,638
Natural gas						359,759						348,024
Construction work in progress						29,053						12,460
TOTAL UTILITY PLANT						2,213,940						2,182,122
Less - accumulated depreciation and amortization						755,956						740,796
UTILITY PLANT - NET						1,457,984						1,441,326
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Deferred fuel costs						4,080						4,080
Other regulatory assets (includes securitization property of $30,995 as of June 30, 2021 and $35,559 as of December 31, 2020)						231,752						266,790
Other						32,970						23,931
TOTAL						268,802						294,801
TOTAL ASSETS						$1,909,164						$1,938,906
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
June 30, 2021 and December 31, 2020
(Unaudited)
						2021						2020
						(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt						$70,000						$—
Payable due to associated company						1,618						1,618
Accounts payable:
Associated companies						77,066						54,234
Other						34,389						60,766
Customer deposits						27,313						27,912
Taxes accrued						5,648						4,700
Interest accrued						6,780						8,095
Deferred fuel costs						2,293						—
Current portion of unprotected excess accumulated deferred income taxes						3,295						3,296
Other						6,279						5,462
TOTAL						234,681						166,083
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued						343,485						338,714
Accumulated deferred investment tax credits						16,067						16,095
Regulatory liability for income taxes - net						54,637						55,675
Asset retirement cost liabilities						3,898						3,768
Accumulated provisions						49,746						89,898
Long-term debt (includes securitization bonds of $35,664 as of June 30, 2021 and $41,291 as of December 31, 2020)						554,341						629,704
Long-term payable due to associated company						10,911						10,911
Other						28,079						21,141
TOTAL						1,061,164						1,165,906
Commitments and Contingencies
EQUITY
Member's equity						613,319						606,917
TOTAL						613,319						606,917
TOTAL LIABILITIES AND EQUITY						$1,909,164						$1,938,906
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Six Months Ended June 30, 2021 and 2020
(Unaudited)
			Member's Equity
			(In Thousands)
Balance at December 31, 2019			$497,579
Net income			11,186
Balance at March 31, 2020			508,765
Net income			4,929
Balance at June 30, 2020			$513,694
Balance at December 31, 2020			$606,917
Net income			1,771
Balance at March 31, 2021			608,688
Net income			4,631
Balance at June 30, 2021			$613,319
See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

The COVID-19 Pandemic

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

Hurricane Laura and Hurricane Delta

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Laura and Hurricane Delta” in the Form 10-K for a discussion of Hurricane Laura and Hurricane Delta, which caused significant damage to portions of Entergy Texas’s service territory. See Note 2 to the financial statements herein for discussion of storm cost filings made in 2021 by Entergy Texas.

Winter Storm Uri

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - February 2021 Winter Storms” in the Form 10-K for a discussion of the winter storms and extreme cold temperatures experienced in the United States, including Entergy Texas’s service area, in February 2021 (Winter Storm Uri). Fuel and purchased power costs for Entergy Texas were approximately $185 million in February 2021 compared to approximately $50 million in February 2020. See Note 2 to the financial statements herein for discussion of storm cost filings made in 2021 by Entergy Texas. See Note 2 to the financial statements herein and in the Form 10-K for discussion of fuel cost recovery at Entergy Texas.

Results of Operations

Net Income

Second Quarter 2021 Compared to Second Quarter 2020

Net income decreased $2.1 million primarily due to higher other operation and maintenance expenses, higher depreciation and amortization expenses, lower other income, and lower volume/weather. The decrease was partially offset by higher retail electric price.

Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020

Net income increased $15.3 million primarily due to higher retail electric price and higher volume/weather. The increase was partially offset by higher depreciation and amortization expenses, lower other income, higher other operation and maintenance expenses, and a higher effective tax rate.

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Operating Revenues

Second Quarter 2021 Compared to Second Quarter 2020

Following is an analysis of the change in operating revenues comparing the second quarter 2021 to the second quarter 2020:

			Amount
			(In Millions)
2020 operating revenues			$372.2
Fuel, rider, and other revenues that do not significantly affect net income			32.3
Retail electric price			31.8
Volume/weather			(5.9)
2021 operating revenues			$430.4

Entergy Texas’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The retail electric price variance is primarily due to the implementation of the generation cost recovery rider, which includes the first-year revenue requirement for the Montgomery County Power Station, effective January 2021, an increase in the transmission cost recovery factor rider effective March 2021, and an increase in the distribution cost recovery factor rider effective March 2021. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the generation cost recovery rider and transmission and distribution cost recovery factor rider filings.

The volume/weather variance is primarily due to a decrease in usage during the unbilled sales period, partially offset by an increase in commercial usage resulting from reduced impacts from the COVID-19 pandemic on businesses as compared to prior year and an increase in industrial usage. The increase in industrial usage is primarily due to an increase in demand from expansion projects, primarily in the transportation and chemicals industries, and an increase in demand from cogeneration customers. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - The COVID-19 Pandemic” in the Form 10-K for a discussion of the COVID-19 pandemic.

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Billed electric energy sales for Entergy Texas for the three months ended June 30, 2021 and 2020 are as follows:

			2021						2020						% Change
			(GWh)
Residential			1,318						1,386						(5)
Commercial			1,085						1,033						5
Industrial			2,213						2,013						10
Governmental			61						62						(2)
Total retail			4,677						4,494						4
Sales for resale:
Associated companies			363						320						13
Non-associated companies			291						225						29
Total			5,331						5,039						6

See Note 13 to the financial statements herein for additional discussion of Entergy Texas’s operating revenues.

Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020

Following is an analysis of the change in operating revenues comparing the six months ended June 30, 2021 to the six months ended June 30, 2020:

			Amount
			(In Millions)
2020 operating revenues			$711.5
Fuel, rider, and other revenues that do not significantly affect net income			136.8
Retail electric price			50.5
Volume/weather			11.9
2021 operating revenues			$910.7

Entergy Texas’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The retail electric price variance is primarily due to the implementation of the generation cost recovery rider, which includes the first-year revenue requirement for the Montgomery County Power Station, effective January 2021, an increase in the transmission cost recovery factor rider effective March 2021, and an increase in the distribution cost recovery factor rider effective March 2021. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the generation cost recovery rider and transmission and distribution cost recovery factor rider filings.

The volume/weather variance is primarily due to an increase of 427 GWh, or 5%, in billed electricity usage, including the effect of more favorable weather on residential sales and an increase in industrial usage. The increase in industrial usage is primarily due to an increase in demand from expansion projects, primarily in the transportation and chemicals industries, and an increase in demand from cogeneration customers.

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Billed electric energy sales for Entergy Texas for the six months ended June 30, 2021 and 2020 are as follows:

			2021						2020						% Change
			(GWh)
Residential			2,857						2,712						5
Commercial			2,085						2,033						3
Industrial			4,141						3,909						6
Governmental			124						126						(2)
Total retail			9,207						8,780						5
Sales for resale:
Associated companies			659						564						17
Non-associated companies			633						310						104
Total			10,499						9,654						9

See Note 13 to the financial statements herein for additional discussion of Entergy Texas’s operating revenues.

Other Income Statement Variances

Second Quarter 2021 Compared to Second Quarter 2020

Other operation and maintenance expenses increased primarily due to:

•an increase of $5.1 million in non-nuclear generation expenses primarily due to higher expenses associated with the Montgomery County Power Station, which began commercial operation in January 2021, and a higher scope of work performed during plant outages in 2021 as compared to the same period in 2020;

•an increase of $1.1 million as a result of the amount of transmission costs allocated by MISO;

•an increase of $1.0 million in information technology costs due to higher contract costs and higher costs associated with system maintenance;

•an increase of $0.8 million primarily due to contract costs in 2021 related to customer solutions and sustainability initiatives; and

•an increase of $0.8 million in vegetation maintenance costs.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Montgomery County Power Station, which was placed in service in January 2021.

Other income decreased primarily due to a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2020, including the Montgomery County Power Station project, as compared to the same period in 2021.

Interest expense increased primarily due to a decrease in the allowance for borrowed funds used during construction due to higher construction work in progress in 2020, including the Montgomery County Power Station project, as compared to the same period in 2021.

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Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020

Other operation and maintenance expenses increased primarily due to:

•an increase of $6.3 million in non-nuclear generation expenses primarily due to higher long-term service agreement expenses and other expenses associated with the Montgomery County Power Station, which began commercial operation in January 2021;

•an increase of $2.1 million in customer service costs primarily due to an increase in contract work in 2021 as compared to the same period in 2020;

•an increase of $1.4 million as a result of the amount of transmission costs allocated by MISO;

•an increase of $1.3 million in vegetation maintenance costs; and

•an increase of $1.2 million in compensation and benefits costs primarily due to lower healthcare claims activity in 2020 as a result of the COVID-19 pandemic, an increase in healthcare cost rates, and an increase in net periodic pension and other postretirement benefits costs as a result of a decrease in the discount rate used to value the benefit liabilities. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K, Note 6 to the financial statements herein, and Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefit costs.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Montgomery County Power Station, which was placed in service in January 2021.

Other income decreased primarily due to a decrease in the allowance for equity funds used during construction due to higher construction work in progress in 2020, including the Montgomery County Power Station project, as compared to the same period in 2021.

Interest expense increased primarily due to a decrease in the allowance for borrowed funds used during construction due to higher construction work in progress in 2020, including the Montgomery County Power Station project, as compared to the same period in 2021.

Income Taxes

The effective income tax rate was 8.4% for the second quarter 2021 and 8.8% for the six months ended June 30, 2021. The difference in the effective income tax rates for the second quarter 2021 and the six months ended June 30, 2021 versus the federal statutory rate of 21% were primarily due to the amortization of excess accumulated deferred income taxes and certain book and tax differences related to utility plant items. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was 5.2% for the second quarter 2020. The difference in the effective income tax rate for the second quarter 2020 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, book and tax differences related to the allowance for equity funds used during construction, and certain book and tax differences related to utility plant items, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was (2.1%) for the six months ended June 30, 2020. The difference in the effective income tax rate for the six months ended June 30, 2020 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, permanent differences related to income tax deductions for stock-based compensation, book and tax differences related to the allowance for equity funds used during construction, and certain book and tax differences related to utility plant items. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of

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the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 3 to the financial statements in the Form 10-K for discussion of the income tax deductions for stock-based compensation.

Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2021 and 2020 were as follows:

			2021						2020
			(In Thousands)
Cash and cash equivalents at beginning of period			$248,596						$12,929
Cash flow provided by (used in):
Operating activities			119,535						170,548
Investing activities			(350,305)						(464,795)
Financing activities			(17,801)						323,557
Net increase (decrease) in cash and cash equivalents			(248,571)						29,310
Cash and cash equivalents at end of period			$25						$42,239

Operating Activities

Net cash flow provided by operating activities decreased $51 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to increased fuel costs as a result of Winter Storm Uri and an increase of approximately $22 million in storm spending in 2021, primarily due to Hurricane Laura and Hurricane Delta restoration efforts. See “Winter Storm Uri” above for discussion of the incremental fuel and purchased power costs incurred. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of fuel and purchased power cost recovery. See “Hurricane Laura and Hurricane Delta” above for discussion of hurricane restoration efforts.

Investing Activities

Net cash flow used in investing activities decreased $114.5 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to:

•a decrease of $98.3 million in non-nuclear generation construction expenditures primarily due to higher spending in 2020 on the Montgomery County Power Station project;

•a decrease of $69.3 million in transmission construction expenditures primarily due to a lower scope of work on projects performed in 2021 as compared to 2020; and

•the sale of a 7.56% partial interest in the Montgomery County Power Station in June 2021 for approximately $67.9 million. See Note 14 to the financial statements herein for further discussion of the transaction.

The decrease was partially offset by:

•an increase of $73.7 million in distribution construction expenditures primarily due to storm spending in 2021, partially offset by lower spending in 2021 on advanced metering infrastructure. See “Hurricane Laura and Hurricane Delta” above for discussion of hurricane restoration efforts; and

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•the purchase of the Hardin County Peaking Facility in June 2021 for approximately $36.7 million. See Note 14 to the financial statements herein for further discussion of the Hardin County Peaking Facility purchase.

Financing Activities

Entergy Texas’s financing activities used $17.8 million of cash for the six months ended June 30, 2021 compared to providing $323.6 million for the six months ended June 30, 2020 primarily due to the following activity:

•the issuance of $175 million of 3.55% Series mortgage bonds in March 2020;

•the repayment, prior to maturity, of $125 million of 2.55% Series mortgage bonds in May 2021;

•a capital contribution of $85 million received from Entergy Corporation in April 2021 in order to maintain Entergy Texas’s capital structure and in anticipation of various upcoming capital expenditures as compared to a capital contribution of $175 million received from Entergy Corporation in March 2020 in anticipation of upcoming expenditures, including Montgomery County Power Station; and

•money pool activity.

Increases in Entergy Texas’s payable to the money pool are a source of cash flow, and Entergy Texas’s payable to the money pool increased by $63.4 million for the six months ended June 30, 2021. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

Capital Structure

Entergy Texas’s debt to capital ratio is shown in the following table. The decrease in the debt to capital ratio is primarily due to the repayment of long-term debt in 2021 and the $85 million capital contribution received from Entergy Corporation in April 2021.

			June 30, 2021						December 31, 2020
Debt to capital			49.9		%				53.7		%
Effect of excluding the securitization bonds			(0.8		%)				(1.3		%)
Debt to capital, excluding securitization bonds (a)			49.1		%				52.4		%
Effect of subtracting cash			—		%				(2.7		%)
Net debt to net capital, excluding securitization bonds (a)			49.1		%				49.7		%

(a)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 finance 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 Texas uses the debt to capital ratios excluding securitization bonds in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy Texas’s financial condition because the securitization bonds are non-recourse to Entergy Texas, as more fully described in Note 5 to the financial statements in the Form 10-K.  Entergy Texas also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Texas’s financial condition because net debt indicates Entergy Texas’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

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Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Texas’s uses and sources of capital. Following are updates to information provided in the Form 10-K.

Entergy Texas’s receivables from or (payables to) the money pool were as follows:

June 30, 2021						December 31, 2020						June 30, 2020						December 31, 2019
(In Thousands)
($63,437)						$4,601						$7,802						$11,181

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Entergy Texas has a credit facility in the amount of $150 million scheduled to expire in June 2026.  The credit facility includes fronting commitments for the issuance of letters of credit against $30 million of the borrowing capacity of the facility. As of June 30, 2021, there were no cash borrowings and $1.3 million of letters of credit outstanding under the credit facility.  In addition, Entergy Texas is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of June 30, 2021, $18.2 million in letters of credit were outstanding under Entergy Texas’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

Liberty County Solar Facility

In September 2020, Entergy Texas filed an application seeking PUCT approval to amend Entergy Texas’s certificate of convenience and necessity to acquire the 100 MW Liberty County Solar Facility and a determination that Entergy Texas’s acquisition of the facility through a tax equity partnership is in the public interest. In its preliminary order, the PUCT determined that, in considering Entergy Texas’s application, it would not specifically address whether Entergy Texas’s use of a tax equity partnership is in the public interest. In March 2021 intervenors and PUCT staff filed testimony, and Entergy Texas filed rebuttal testimony in April 2021. A hearing on the merits was held in April 2021. Post-hearing and reply briefing was completed in May 2021. In July 2021 the presiding administrative law judges issued a proposal for decision recommending that the PUCT deny the certification requested in the application. This proposal for decision is subject to change based on exceptions filed by the parties. Once it is final, it will be presented to the PUCT, which may adopt or modify it. A decision by the PUCT is expected in September 2021. Closing, subject to receipt of required regulatory approvals and other conditions, is expected to occur in 2023.

State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - State and Local Rate Regulation and Fuel-Cost Recovery” in the Form 10-K for a discussion of state and local rate regulation and fuel-cost recovery. The following are updates to that discussion.

Distribution Cost Recovery Factor (DCRF) Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $26.3 million annually, or $6.8 million in incremental annual revenues beyond Entergy Texas’s then-effective DCRF rider based on its capital invested in distribution between January 1, 2020 and August 31, 2020. In February 2021 the administrative law judge with the State Office of Administrative Hearings approved Entergy Texas’s

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agreed motion for interim rates, which went into effect in March 2021. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested DCRF revenue requirement and resolving all issues in the proceeding. In May 2021 the PUCT issued an order approving the settlement.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed rider is designed to collect from Entergy Texas’s retail customers approximately $51 million annually, or $31.6 million in incremental annual revenues beyond Entergy Texas’s then-effective TCRF rider based on its capital invested in transmission between July 1, 2019 and August 31, 2020. A procedural schedule was established with a hearing scheduled in March 2021. In February 2021, Entergy Texas filed an agreed motion to abate the procedural schedule, noting that the parties had reached a settlement in principle, and the administrative law judge granted the motion to abate. In March 2021 the parties filed an unopposed settlement recommending that Entergy Texas be allowed to collect its full requested TCRF revenue requirement with interim rates effective March 2021 and resolving all issues in the proceeding. In March 2021 the administrative law judge granted the motion for interim rates, admitted evidence, and remanded this case to the PUCT for consideration of a final order at a future open meeting. In June 2021 the PUCT issued an order approving the settlement.

Fuel and purchased power recovery

In February 2021, Entergy Texas filed an application to implement a fuel refund for a cumulative over-recovery of approximately $75 million that is primarily attributable to settlements received by Entergy Texas from MISO related to Hurricane Laura. Entergy Texas planned to issue the refund over the period of March through August 2021. On February 22, 2021, Entergy Texas filed a motion to abate its fuel refund proceeding to assess how the February 2021 winter storm impacted Entergy Texas’s fuel over-recovery position. In March 2021, Entergy Texas withdrew its application to implement the fuel refund. Entergy Texas is continuing to evaluate its fuel balance and will file a subsequent refund or surcharge application consistent with the requirements of the PUCT’s rules.

COVID-19 Orders

As discussed in the Form 10-K, in March 2020 the PUCT authorized electric utilities to record as a regulatory asset expenses resulting from the effects of the COVID-19 pandemic. In future proceedings the PUCT will consider whether each utility's request for recovery of these regulatory assets is reasonable and necessary, the appropriate period of recovery, and any amount of carrying costs thereon. In March 2020 the PUCT ordered a moratorium on disconnections for nonpayment for all customer classes, but, in April 2020, revised the disconnect moratorium to apply only to residential customers. The PUCT allowed the moratorium to expire on June 13, 2020, but on July 17, 2020, the PUCT re-established the disconnect moratorium for residential customers until August 31, 2020. In January 2021, Entergy Texas resumed disconnections for customers with past-due balances that have not made payment arrangements. As of June 30, 2021, Entergy Texas recorded a regulatory asset of $14.2 million for costs associated with the COVID-19 pandemic.

Generation Cost Recovery Rider

As discussed in the Form 10-K, in October 2020, Entergy Texas filed an application to establish a generation cost recovery rider with an initial annual revenue requirement of approximately $91 million to begin recovering a return of and on its capital investment in the Montgomery County Power Station through August 31, 2020. In December 2020, Entergy Texas filed an unopposed settlement supporting a generation cost recovery rider with an annual revenue requirement of approximately $86 million, with the ability to seek recovery of a majority of the remaining requested costs in a subsequent rate case. On January 14, 2021, the PUCT approved the generation cost recovery rider settlement rates on an interim basis and abated the proceeding. In March 2021, Entergy Texas

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filed to update its generation cost recovery rider to include investment in Montgomery County Power Station after August 31, 2020. In April 2021 the administrative law judge issued an order unabating the proceeding and in May 2021 the administrative law judge issued an order finding Entergy Texas’s application and notice of the application to be sufficient. In May 2021, Entergy Texas filed an amendment to the application to reflect the PUCT’s approval of the sale of a 7.56% partial interest in the Montgomery County Power Station to East Texas Electric Cooperative, Inc., which closed in June 2021. In June 2021 the PUCT referred the proceeding to the State Office of Administrative Hearings. In July 2021 the administrative law judge with the State Office of Administrative Hearings adopted a procedural schedule setting a hearing on the merits for September 2021. In July 2021 the parties filed a motion to abate the procedural schedule noting they had reached an agreement in principle and to allow the parties time to finalize a settlement agreement, which motion was granted by the administrative law judge.

In December 2020, Entergy Texas also filed an application to amend its generation cost recovery rider to reflect its acquisition of the Hardin County Peaking Facility, which closed in June 2021. Because Hardin was to be acquired in the future, the initial generation cost recovery rider rates proposed in the application represent no change from the generation cost recovery rider rates to be established in Entergy Texas’s previous generation cost recovery rider proceeding. In July 2021 the PUCT issued an order approving the application. In August 2021, Entergy Texas filed an update application to recover its actual investment in the acquisition of the Hardin County Peaking Facility. See Note 14 to the financial statements herein for further discussion of the Hardin County Peaking Facility purchase.

Storm Cost Filings

In August 2020 and October 2020, Hurricane Laura and Hurricane Delta caused extensive damage to Entergy Texas’s service area. In February 2021, Winter Storm Uri also caused damage to Entergy Texas’s service area. The storms resulted in widespread power outages, significant damage primarily to distribution and transmission infrastructure, and the loss of sales during the power outages. In April 2021, Entergy Texas filed an application with the PUCT requesting a determination that its system restoration costs associated with Hurricane Laura, Hurricane Delta, and Winter Storm Uri of approximately $250 million, including approximately $200 million in capital costs and approximately $50 million in non-capital costs were reasonable and necessary to enable Entergy Texas to restore electric service to its customers and Entergy Texas’s electric utility infrastructure. The filing currently includes only a portion of the Winter Storm Uri costs. In July 2021, Entergy Texas filed with the PUCT an application for a financing order to approve the securitization of the system restoration costs that are the subject of the April 2021 application. As stated in the July 2021 application, Entergy Texas also plans to seek a separate financing order, in a separate application and docket, under the newly-enacted Subchapter J of Chapter 36 of the Public Utility Regulatory Act, titled “Lower-Cost Financing Mechanism for Securitization for Recovery of System Restoration Costs.” However, the ability to timely utilize that mechanism for securitization of the system restoration costs that are approved for recovery is dependent on certain events outside of Entergy Texas’s control, which may necessitate utilizing the traditional structure for securitization of the system restoration costs as may be approved for recovery in the proceeding initiated in July 2021. In either event, only one financing order would ultimately be utilized for the securitization of system restoration costs approved for recovery by the PUCT. A procedural schedule was established with a hearing on the merits in September 2021.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation. 

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Nuclear Matters” in the Form 10-K for discussion of nuclear matters.

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Industrial and Commercial Customers

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Industrial and Commercial Customers” in the Form 10-K for a discussion of industrial and commercial customers.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of utility regulatory accounting, impairment of long-lived assets, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2021 and 2020
(Unaudited)
						Three Months Ended												Six Months Ended
						2021						2020						2021						2020
						(In Thousands)												(In Thousands)
OPERATING REVENUES
Electric						$430,434						$372,194						$910,654						$711,530
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale						64,031						47,790						176,427						89,136
Purchased power						128,699						124,351						270,061						244,142
Other operation and maintenance						70,815						60,527						133,770						119,460
Taxes other than income taxes						20,671						20,524						42,546						39,796
Depreciation and amortization						53,587						43,835						104,523						86,401
Other regulatory charges (credits) - net						25,253						18,724						41,093						40,092
TOTAL						363,056						315,751						768,420						619,027
OPERATING INCOME						67,378						56,443						142,234						92,503
OTHER INCOME
Allowance for equity funds used during construction						2,670						11,601						5,115						22,242
Interest and investment income						204						343						428						772
Miscellaneous - net						(527)						(791)						(950)						(1,137)
TOTAL						2,347						11,153						4,593						21,877
INTEREST EXPENSE
Interest expense						21,899						23,137						44,937						45,995
Allowance for borrowed funds used during construction						(1,075)						(4,985)						(2,059)						(9,558)
TOTAL						20,824						18,152						42,878						36,437
INCOME BEFORE INCOME TAXES						48,901						49,444						103,949						77,943
Income taxes						4,111						2,576						9,101						(1,632)
NET INCOME						44,790						46,868						94,848						79,575
Preferred dividend requirements						471						471						941						941
EARNINGS APPLICABLE TO COMMON STOCK						$44,319						$46,397						$93,907						$78,634
See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2021 and 2020
(Unaudited)
						2021						2020
						(In Thousands)
OPERATING ACTIVITIES
Net income						$94,848						$79,575
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization						104,523						86,401
Deferred income taxes, investment tax credits, and non-current taxes accrued						5,237						9,470
Changes in assets and liabilities:
Receivables						(33,522)						(20,524)
Fuel inventory						3,606						1,222
Accounts payable						1,530						(3,543)
Taxes accrued						(4,057)						(11,390)
Interest accrued						(1,072)						359
Deferred fuel costs						(72,537)						17,226
Other working capital accounts						(3,285)						9,928
Provisions for estimated losses						314						91
Other regulatory assets						43,619						50,347
Other regulatory liabilities						(2,036)						(23,947)
Pension and other postretirement liabilities						(11,050)						(13,825)
Other assets and liabilities						(6,583)						(10,842)
Net cash flow provided by operating activities						119,535						170,548
INVESTING ACTIVITIES
Construction expenditures						(401,362)						(495,560)
Allowance for equity funds used during construction						5,115						22,242
Proceeds from sale of assets						67,920						—
Payment for purchase of assets						(36,534)						(4,931)
Changes in money pool receivable - net						4,601						3,379
Changes in securitization account						9,955						10,075
Net cash flow used in investing activities						(350,305)						(464,795)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt						—						194,256
Retirement of long-term debt						(170,429)						(43,376)
Capital contribution from parent						85,000						175,000
Change in money pool payable - net						63,437						—
Preferred stock dividends paid						(941)						(1,124)
Other						5,132						(1,199)
Net cash flow provided by (used in) financing activities						(17,801)						323,557
Net increase (decrease) in cash and cash equivalents						(248,571)						29,310
Cash and cash equivalents at beginning of period						248,596						12,929
Cash and cash equivalents at end of period						$25						$42,239
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized						$44,760						$44,683
Income taxes						$9,710						$4,031
See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
June 30, 2021 and December 31, 2020
(Unaudited)
						2021						2020
						(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash						$25						$26
Temporary cash investments						—						248,570
Total cash and cash equivalents						25						248,596
Securitization recovery trust account						26,278						36,233
Accounts receivable:
Customer						111,163						103,221
Allowance for doubtful accounts						(12,223)						(16,810)
Associated companies						17,494						18,892
Other						17,328						11,780
Accrued unbilled revenues						68,654						56,411
Total accounts receivable						202,416						173,494
Fuel inventory - at average cost						49,925						53,531
Materials and supplies - at average cost						63,417						56,227
Prepayments and other						15,055						20,165
TOTAL						357,116						588,246
OTHER PROPERTY AND INVESTMENTS
Investments in affiliates - at equity						324						349
Non-utility property - at cost (less accumulated depreciation)						376						376
Other						17,744						19,889
TOTAL						18,444						20,614
UTILITY PLANT
Electric						6,918,133						6,007,687
Construction work in progress						181,473						879,908
TOTAL UTILITY PLANT						7,099,606						6,887,595
Less - accumulated depreciation and amortization						1,981,761						1,864,494
UTILITY PLANT - NET						5,117,845						5,023,101
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $52,330 as of June 30, 2021 and $78,590 as of December 31, 2020)						481,094						524,713
Other						81,501						70,397
TOTAL						562,595						595,110
TOTAL ASSETS						$6,056,000						$6,227,071
See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
June 30, 2021 and December 31, 2020
(Unaudited)
						2021						2020
						(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt						$75,000						$200,000
Accounts payable:
Associated companies						110,028						55,944
Other						179,398						350,947
Customer deposits						33,437						36,282
Taxes accrued						48,381						52,438
Interest accrued						19,784						20,856
Current portion of unprotected excess accumulated deferred income taxes						29,855						29,249
Deferred fuel costs						12,819						85,356
Other						14,303						12,370
TOTAL						523,005						843,442
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued						647,348						639,422
Accumulated deferred investment tax credits						9,634						9,942
Regulatory liability for income taxes - net						157,086						175,594
Other regulatory liabilities						48,163						32,297
Asset retirement cost liabilities						8,288						8,063
Accumulated provisions						8,696						8,382
Long-term debt (includes securitization bonds of $77,908 as of June 30, 2021 and $123,066 as of December 31, 2020)						2,248,879						2,293,708
Other						68,416						58,643
TOTAL						3,196,510						3,226,051
Commitments and Contingencies
EQUITY
Common stock, no par value, authorized 200,000,000 shares; issued and outstanding 46,525,000 shares in 2021 and 2020						49,452						49,452
Paid-in capital						1,040,162						955,162
Retained earnings						1,211,871						1,117,964
Total common shareholder's equity						2,301,485						2,122,578
Preferred stock without sinking fund						35,000						35,000
TOTAL						2,336,485						2,157,578
TOTAL LIABILITIES AND EQUITY						$6,056,000						$6,227,071
See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Six Months Ended June 30, 2021 and 2020
(Unaudited)
									Common Equity
			Preferred Stock						Common Stock						Paid-in Capital						Retained Earnings						Total
			(In Thousands)
Balance at December 31, 2019			$35,000						$49,452						$780,182						$934,773						$1,799,407
Net income			—						—						—						32,707						32,707
Capital contribution from parent			—						—						175,000						—						175,000
Preferred stock dividends			—						—						—						(470)						(470)
Balance at March 31, 2020			35,000						49,452						955,182						967,010						2,006,644
Net income			—						—						—						46,868						46,868
Preferred stock dividends			—						—						—						(471)						(471)
Other			—						—						(10)						—						(10)
Balance at June 30, 2020			$35,000						$49,452						$955,172						$1,013,407						$2,053,031
Balance at December 31, 2020			$35,000						$49,452						$955,162						$1,117,964						$2,157,578
Net income			—						—						—						50,058						50,058
Preferred stock dividends			—						—						—						(470)						(470)
Balance at March 31, 2021			35,000						49,452						955,162						1,167,552						2,207,166
Net income			—						—						—						44,790						44,790
Capital contribution from parent			—						—						85,000						—						85,000
Preferred stock dividends			—						—						—						(471)						(471)
Balance at June 30, 2021			$35,000						$49,452						$1,040,162						$1,211,871						$2,336,485
See Notes to Financial Statements.

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SYSTEM ENERGY RESOURCES, INC.

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

System Energy’s principal asset currently consists of an ownership interest and a 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

Second Quarter 2021 Compared to Second Quarter 2020

Net income increased $1.3 million primarily due to changes in rate base.

Six Months Ended June 30, 2021 Compared to Six Months Ended June 30, 2020

Net income decreased $3.3 million primarily due to changes in rate base and a decrease in the allowance for equity funds used during construction resulting from higher spending in 2020 including the scheduled 2020 Grand Gulf refueling outage.

Income Taxes

The effective income tax rate was 22.8% for the second quarter 2021. The difference in the effective income tax rate for the second quarter 2021 versus the federal statutory rate of 21% was primarily due to state income taxes.

The effective income tax rate was (3.1%) for the six months ended June 30, 2021. The difference in the effective income tax rate for the six months ended June 30, 2021 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was 20.5% for the second quarter 2020. The difference in the effective income tax rate for the second quarter 2020 versus the federal statutory rate of 21% was primarily due to certain book and tax differences related to utility plant items and book and tax differences related to the allowance for equity funds used during construction, partially offset by state income taxes.

The effective income tax rate was 18.4% for the six months ended June 30, 2020. The difference in the effective income tax rate for the six months ended June 30, 2020 versus the federal statutory rate of 21% was primarily due to certain book and tax differences related to utility plant items, book and tax differences related to the allowance for equity funds used during construction, and permanent differences related to income tax deductions for stock-based compensation, partially offset by state income taxes. See Note 3 to the financial statements in the Form 10-K for discussion of the income tax deductions for stock-based compensation.

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Management's Financial Discussion and Analysis

Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2021 and 2020 were as follows:

			2021						2020
			(In Thousands)
Cash and cash equivalents at beginning of period			$242,469						$68,534
Cash flow provided by (used in):
Operating activities			44,451						84,736
Investing activities			(86,677)						(157,713)
Financing activities			(81,021)						4,550
Net decrease in cash and cash equivalents			(123,247)						(68,427)
Cash and cash equivalents at end of period			$119,222						$107

Operating Activities

Net cash flow provided by operating activities decreased $40.3 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to income tax payments of $39.1 million in 2021 and timing of collections of receivables, partially offset by a decrease in spending of $35.2 million on nuclear refueling outages in 2021 as compared to the same period in 2020 and timing of payments to vendors. System Energy had income tax payments in 2021 as a result of the amended Mississippi tax returns filed based on federal adjustments related to the resolution of the 2014-2015 IRS audit, as well as a portion of the payments made in accordance with an intercompany income tax allocation agreement. See Note 3 to the financial statements in the Form 10-K for discussion of the 2014-2015 IRS audit.

Investing Activities

Net cash flow used in investing activities decreased $71 million for the six months ended June 30, 2021 compared to the six months ended June 30, 2020 primarily due to:

•a decrease of $111 million in nuclear construction expenditures as a result of spending in 2020 on Grand Gulf outage projects and upgrades; and

•an increase of $67.2 million as a result of fluctuations in nuclear fuel activity because of variations from year to year in the timing and pricing of fuel reload requirements in the Utility business, material and services deliveries, and the timing of cash payments during the nuclear fuel cycle.

The decrease was partially offset by money pool activity.

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 $56.1 million for the six months ended June 30, 2021 compared to decreasing by $59.3 million for the six months ended June 30, 2020. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

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Financing Activities

System Energy’s financing activities used $81 million of cash for the six months ended June 30, 2021 compared to providing $4.6 million of cash for the six months ended June 30, 2020 primarily due to the following activity:

•the repayment in February 2021 of $100 million of 3.42% Series J notes by the System Energy nuclear fuel company variable interest entity;

•money pool activity; and

•a decrease of $33.7 million in common stock dividends and distributions in order to maintain System Energy’s capital structure.

Increases in System Energy’s payable to the money pool is a source of cash flow, and System Energy’s payable to the money pool increased by $15.8 million for the six months ended June 30, 2020.

See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

Capital Structure

System Energy’s debt to capital ratio is shown in the following table. The decrease in the debt to capital ratio is primarily due to the net repayment of long-term debt in 2021.

			June 30, 2021						December 31, 2020
Debt to capital			40.4		%				42.7		%
Effect of subtracting cash			(4.1		%)				(8.5		%)
Net debt to net capital			36.3		%				34.2		%

Net debt consists of debt less cash and cash equivalents.  Debt consists of short-term borrowings and long-term debt, including the currently maturing portion.  Capital consists of debt and common equity.  Net capital consists of capital less cash and cash equivalents.  System Energy uses the debt to 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.  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 because net debt indicates System Energy’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of System Energy’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.

System Energy’s receivables from or (payables to) the money pool were as follows:

June 30, 2021						December 31, 2020						June 30, 2020						December 31, 2019
(In Thousands)
$60,111						$4,004						($15,774)						$59,298

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

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The System Energy nuclear fuel company variable interest entity has a credit facility in the amount of $120 million scheduled to expire in June 2024. As of June 30, 2021, $45.7 million in loans were outstanding under the System Energy nuclear fuel company variable interest entity credit facility. See Note 4 to the financial statements herein for additional discussion of the variable interest entity credit facility.

Federal Regulation

See the “Rate, Cost-recovery, and Other Regulation - Federal Regulation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K and Note 2 to the financial statements herein and in the Form 10-K for a discussion of federal regulation.

Complaints Against System Energy

Return on Equity and Capital Structure Complaints

As discussed in the Form 10-K, in May 2020 the FERC issued an order on rehearing of Opinion No. 569 (Opinion No. 569-A). In June 2020 the procedural schedule in the System Energy proceeding was further revised in order to allow parties to address the Opinion No. 569-A methodology. The parties and FERC trial staff filed final rounds of testimony in August 2020. The hearing before a FERC ALJ occurred in late-September through early-October 2020, post-hearing briefing took place in November and December 2020.

In March 2021 the FERC ALJ issued an initial decision. With regard to System Energy’s authorized return on equity, the ALJ determined that the existing return on equity of 10.94% is no longer just and reasonable, and that the replacement authorized return on equity, based on application of the Opinion No. 569-A methodology, should be 9.32%. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (January 2017-April 2018) based on the difference between the current return on equity and the replacement authorized return on equity. The ALJ determined that the April 2018 complaint concerning the authorized return on equity should be dismissed, and that no refunds for a second fifteen-month refund period should be due. With regard to System Energy’s capital structure, the ALJ determined that System Energy’s actual equity ratio is excessive and that the just and reasonable equity ratio is 48.15% equity, based on the average equity ratio of the proxy group used to evaluate the return on equity for the second complaint. The ALJ further determined that System Energy should pay refunds for a fifteen-month refund period (September 2018-December 2019) based on the difference between the actual equity ratio and the 48.15% equity ratio. If the ALJ’s initial decision is upheld, the estimated refund for this proceeding is approximately $59 million, which includes interest through June 30, 2021, and the estimated resulting annual rate reduction would be approximately $46 million. The estimated refund will continue to accrue interest until a final FERC decision is issued. Based on the course of the proceeding to date, System Energy has recorded a provision of $37 million, including interest, as of June 30, 2021.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. In April 2021, System Energy filed its brief on exceptions, in which it challenged the initial decision’s findings on both the return on equity and capital structure issues. Also in April 2021, the LPSC, APSC, MPSC, City Council, and the FERC trial staff filed briefs on exceptions. Reply briefs opposing exceptions were filed in May 2021 by System Energy, the FERC trial staff, the LPSC, APSC, MPSC, and the City Council. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. A hearing was held before a FERC ALJ in

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November 2019. In April 2020 the ALJ issued the initial decision. Among other things, the ALJ determined that refunds were due on three main issues. First, with regard to the lease renewal payments, the ALJ determined that System Energy is recovering an unjust acquisition premium through the lease renewal payments, and that System Energy’s recovery from customers through rates should be limited to the cost of service based on the remaining net book value of the leased assets, which is approximately $70 million. The ALJ found that the remedy for this issue should be the refund of lease payments (approximately $17.2 million per year since July 2015) with interest determined at the FERC quarterly interest rate, which would be offset by the addition of the net book value of the leased assets in the cost of service. The ALJ did not calculate a value for the refund expected as a result of this remedy. In addition, System Energy would no longer recover the lease payments in rates prospectively. Second, with regard to the liabilities associated with uncertain tax positions, the ALJ determined that the liabilities are accumulated deferred income taxes and that System Energy’s rate base should have been reduced for those liabilities. If the ALJ’s initial decision is upheld, the estimated refund for this issue through June 30, 2021, is approximately $422 million, plus interest, which is approximately $119 million through June 30, 2021. The ALJ also found that System Energy should include liabilities associated with uncertain tax positions as a rate base reduction going forward. Third, with regard to the depreciation expense adjustments, the ALJ found that System Energy should correct for the error in re-billings retroactively and prospectively, but that System Energy should not be permitted to recover interest on any retroactive return on enhanced rate base resulting from such corrections. If the initial decision is affirmed on this issue, System Energy estimates refunds of approximately $19 million, which includes interest through June 30, 2021.

The ALJ initial decision is an interim step in the FERC litigation process, and an ALJ’s determinations made in an initial decision are not controlling on the FERC. The ALJ in the initial decision acknowledges that these are issues of first impression before the FERC. The case is pending before the FERC, which will review the case and issue an order on the proceeding, and the FERC may accept, reject, or modify the ALJ’s initial decision in whole or in part. Refunds, if any, that might be required will only become due after the FERC issues its order reviewing the initial decision.

Also as discussed in the Form 10-K, in November 2020 the IRS issued a Revenue Agent’s Report (RAR) for the 2014/2015 tax year and in December 2020 Entergy executed it. The RAR contained an adjustment to System Energy’s uncertain nuclear decommissioning tax position. As a result of the RAR, in December 2020, System Energy filed amendments to its new Federal Power Act section 205 filings to establish an ongoing rate base credit for the accumulated deferred income taxes resulting from the decommissioning uncertain tax position and to credit excess accumulated deferred income taxes arising from the successful portion of the decommissioning uncertain tax position. The amendments both propose the inclusion of the RAR as support for the filings. In December 2020 the LPSC, APSC, and City Council filed a protest in response to the amendments, reiterating their prior objections to the filings. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filings subject to refund, setting them for hearing, and holding the hearing in abeyance.

In December 2020, System Energy filed a new Federal Power Act section 205 filing to provide a one-time, historical credit to customers of $25.2 million for the accumulated deferred income taxes that would have been created by the decommissioning uncertain tax position if the IRS’s decision had been known in 2016. In January 2021 the LPSC, APSC, MPSC, and City Council filed a protest to the filing. In February 2021 the FERC issued an order accepting System Energy’s Federal Power Act section 205 filing subject to refund, setting it for hearing, and holding the hearing in abeyance. The one-time credit was made during the first quarter 2021.

LPSC Authorization of Additional Complaints

As discussed in the Form 10-K, in May 2020 the LPSC authorized its staff to file additional complaints at the FERC related to the rates charged by System Energy for Grand Gulf energy and capacity supplied to Entergy Louisiana under the Unit Power Sales Agreement. The LPSC directive notes that the initial decision issued by the presiding ALJ in the Grand Gulf sale-leaseback complaint proceeding did not address, for procedural reasons, certain rate issues raised by the LPSC and declined to order further investigation of rates charged by System

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Energy. The LPSC directive authorizes its staff to file complaints at the FERC “necessary to address these rate issues, to request a full investigation into the rates charged by System Energy for Grand Gulf power, and to seek rate refund, rate reduction, and such other remedies as may be necessary and appropriate to protect Louisiana ratepayers.” The LPSC directive further stated that the LPSC has seen “information suggesting that the Grand Gulf plant has been significantly underperforming compared to other nuclear plants in the United States, has had several extended and unexplained outages, and has been plagued with serious safety concerns.” The LPSC expressed concern that the costs paid by Entergy Louisiana's retail customers may have been detrimentally impacted, and authorized “the filing of a FERC complaint to address these performance issues and to seek appropriate refund, rate reduction, and other remedies as may be appropriate.”

Unit Power Sales Agreement Complaint

The first of the additional complaints was filed by the LPSC, the APSC, the MPSC and the City Council in September 2020. The first complaint raises two sets of rate allegations: violations of the filed rate and a corresponding request for refunds for prior periods; and elements of the Unit Power Sales Agreement are unjust and unreasonable and a corresponding request for refunds for the 15-month refund period and changes to the Unit Power Sales Agreement prospectively. In May 2021 the FERC issued an order addressing the complaint, establishing a refund effective date of September 21, 2020, establishing hearing procedures, and holding those procedures in abeyance pending the FERC’s review of the initial decision in the Grand Gulf sale-leaseback renewal complaint discussed above. System Energy agreed that the hearing should be held in abeyance but sought rehearing of the FERC’s decision as related to matters set for hearing that were beyond the scope of the FERC’s jurisdiction or authority. The complainants sought rehearing of the FERC’s decision to hold the hearing in abeyance and filed a motion to proceed, which motion System Energy subsequently opposed. In June 2021, System Energy’s request for rehearing was denied by operation of law, and System Energy filed an appeal of the FERC’s orders in the Court of Appeals for the Fifth Circuit. The appeal is currently in abeyance.

Grand Gulf Prudence Complaint

The second of the additional complaints was filed at the FERC in March 2021 by the LPSC, the APSC, and the City Council against System Energy, Entergy Services, Entergy Operations, and Entergy Corporation. The second complaint contains two primary allegations. First, it alleges that, based on the plant’s capacity factor and alleged safety performance, System Energy and the other respondents imprudently operated Grand Gulf during the period 2016-2020, and it seeks refunds of at least $360 million in alleged replacement energy costs, in addition to other costs, including those that can only be identified upon further investigation. Second, it alleges that the performance and/or management of the 2012 extended power uprate of Grand Gulf was imprudent, and it seeks refunds of all costs of the 2012 uprate that are determined to result from imprudent planning or management of the project. In addition to the requested refunds, the complaint asks that the FERC modify the Unit Power Sales Agreement to provide for full cost recovery only if certain performance indicators are met and to require pre-authorization of capital improvement projects in excess of $125 million before related costs may be passed through to customers in rates. In April 2021, System Energy and the other respondents filed their motion to dismiss and answer to the complaint. System Energy requested that the FERC dismiss the claims within the complaint. With respect to the claim concerning operations, System Energy argues that the complaint does not meet its legal burden because, among other reasons, it fails to allege any specific imprudent conduct. With respect to the claim concerning the uprate, System Energy argues that the complaint fails because, among other reasons, the complainants’ own conduct prevents them from raising a serious doubt as to the prudence of the uprate. System Energy also requests that the FERC dismiss other elements of the complaint, including the proposed modifications to the Unit Power Sales Agreement, because they are not warranted. Additional responsive pleadings were filed by the complainants and System Energy during the period from March through July 2021.

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Management's Financial Discussion and Analysis

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of nuclear matters. Following is an update to that discussion

NRC Reactor Oversight Process

As discussed in the Form 10-K, the NRC’s Reactor Oversight Process is a program to collect information about plant performance, assess the information for its safety significance, and provide for appropriate licensee and NRC response. The NRC evaluates plant performance by analyzing two distinct inputs: inspection findings resulting from the NRC’s inspection program and performance indicators reported by the licensee. The evaluations result in the placement of each plant in one of the NRC’s Reactor Oversight Process Action Matrix columns: “licensee response column,” or Column 1, “regulatory response column,” or Column 2, “degraded cornerstone column,” or Column 3, and “multiple/repetitive degraded cornerstone column,” or Column 4. Plants in Column 1 are subject to normal NRC inspection activities. Plants in Column 2, Column 3, or Column 4 are subject to progressively increasing levels of inspection by the NRC with, in general, progressively increasing levels of associated costs.

In March 2021 the NRC placed Grand Gulf in Column 3 based on the incidence of five unplanned plant scrams during calendar year 2020, some of which were related to upgrades made to the plant’s turbine control system during the spring 2020 refueling outage. The NRC plans to conduct a supplemental inspection of Grand Gulf in accordance with its inspection procedures for nuclear plants in Column 3.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in System Energy’s accounting for nuclear decommissioning costs, utility regulatory accounting, impairment of long-lived assets, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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SYSTEM ENERGY RESOURCES, INC.
INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2021 and 2020
(Unaudited)
						Three Months Ended												Six Months Ended
						2021						2020						2021						2020
						(In Thousands)												(In Thousands)
OPERATING REVENUES
Electric						$161,313						$126,049						$279,059						$256,713
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale						14,073						6,008						30,932						19,151
Nuclear refueling outage expenses						6,792						5,666						13,510						13,938
Other operation and maintenance						58,047						42,802						100,007						83,273
Decommissioning						9,625						9,248						19,154						18,405
Taxes other than income taxes						6,968						7,105						13,793						15,078
Depreciation and amortization						25,768						27,501						53,962						54,400
Other regulatory charges (credits) - net						(17,550)						(3,517)						(6,000)						(14,077)
TOTAL						103,723						94,813						225,358						190,168
OPERATING INCOME						57,590						31,236						53,701						66,545
OTHER INCOME (DEDUCTIONS)
Allowance for equity funds used during construction						1,355						3,200						2,466						6,784
Interest and investment income						(2,410)						12,108						25,032						17,446
Miscellaneous - net						(7,886)						(2,157)						(9,910)						(4,617)
TOTAL						(8,941)						13,151						17,588						19,613
INTEREST EXPENSE
Interest expense						9,579						8,534						19,114						17,074
Allowance for borrowed funds used during construction						(229)						(634)						(417)						(1,345)
TOTAL						9,350						7,900						18,697						15,729
INCOME BEFORE INCOME TAXES						39,299						36,487						52,592						70,429
Income taxes						8,969						7,496						(1,602)						12,925
NET INCOME						$30,330						$28,991						$54,194						$57,504
See Notes to Financial Statements.

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SYSTEM ENERGY RESOURCES, INC.
STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2021 and 2020
(Unaudited)
						2021						2020
						(In Thousands)
OPERATING ACTIVITIES
Net income						$54,194						$57,504
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization						101,640						88,343
Deferred income taxes, investment tax credits, and non-current taxes accrued						(3,052)						517
Changes in assets and liabilities:
Receivables						(15,877)						18,213
Accounts payable						(3,449)						(18,591)
Taxes accrued						(27,698)						6,020
Interest accrued						(1,102)						(12)
Other working capital accounts						442						(41,850)
Other regulatory assets						60,949						(21,072)
Other regulatory liabilities						49,033						(21,672)
Pension and other postretirement liabilities						(12,243)						(5,354)
Other assets and liabilities						(158,386)						22,690
Net cash flow provided by operating activities						44,451						84,736
INVESTING ACTIVITIES
Construction expenditures						(38,268)						(147,889)
Allowance for equity funds used during construction						2,466						6,784
Nuclear fuel purchases						(11,039)						(75,024)
Proceeds from the sale of nuclear fuel						12,754						9,573
Proceeds from nuclear decommissioning trust fund sales						418,042						275,563
Investment in nuclear decommissioning trust funds						(414,525)						(286,018)
Changes in money pool receivable - net						(56,107)						59,298
Net cash flow used in investing activities						(86,677)						(157,713)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt						453,981						482,533
Retirement of long-term debt						(509,002)						(434,104)
Change in money pool payable - net						—						15,774
Common stock dividends and distributions paid						(26,000)						(59,653)
Net cash flow provided by (used in) financing activities						(81,021)						4,550
Net decrease in cash and cash equivalents						(123,247)						(68,427)
Cash and cash equivalents at beginning of period						242,469						68,534
Cash and cash equivalents at end of period						$119,222						$107
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized						$29,231						$8,589
Income taxes						$39,085						($4,000)
See Notes to Financial Statements.

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SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
ASSETS
June 30, 2021 and December 31, 2020
(Unaudited)
						2021						2020
						(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash						$139						$26,086
Temporary cash investments						119,083						216,383
Total cash and cash equivalents						119,222						242,469
Accounts receivable:
Associated companies						127,194						57,743
Other						5,083						2,550
Total accounts receivable						132,277						60,293
Materials and supplies - at average cost						136,428						123,006
Deferred nuclear refueling outage costs						21,314						34,459
Prepayments and other						6,143						6,864
TOTAL						415,384						467,091
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds						1,312,525						1,215,868
TOTAL						1,312,525						1,215,868
UTILITY PLANT
Electric						5,321,319						5,309,458
Construction work in progress						75,019						59,831
Nuclear fuel						133,364						175,005
TOTAL UTILITY PLANT						5,529,702						5,544,294
Less - accumulated depreciation and amortization						3,351,715						3,355,367
UTILITY PLANT - NET						2,177,987						2,188,927
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets						478,014						538,963
Other						2,277						3,119
TOTAL						480,291						542,082
TOTAL ASSETS						$4,386,187						$4,413,968
See Notes to Financial Statements.

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SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
LIABILITIES AND EQUITY
June 30, 2021 and December 31, 2020
(Unaudited)
						2021						2020
						(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt						$50,324						$100,015
Accounts payable:
Associated companies						18,825						15,309
Other						38,862						41,313
Taxes accrued						55,279						82,977
Interest accrued						11,620						12,722
Other						4,246						4,248
TOTAL						179,156						256,584
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued						349,912						359,835
Accumulated deferred investment tax credits						43,643						38,902
Regulatory liability for income taxes - net						132,794						151,829
Other regulatory liabilities						733,464						665,396
Decommissioning						988,064						968,910
Pension and other postretirement liabilities						113,169						125,412
Long-term debt						700,615						705,259
Other						36,630						61,295
TOTAL						3,098,291						3,076,838
Commitments and Contingencies
COMMON EQUITY
Common stock, no par value, authorized 1,000,000 shares; issued and outstanding 789,350 shares in 2021 and 2020						951,850						951,850
Retained earnings						156,890						128,696
TOTAL						1,108,740						1,080,546
TOTAL LIABILITIES AND EQUITY						$4,386,187						$4,413,968
See Notes to Financial Statements.

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SYSTEM ENERGY RESOURCES, INC.
STATEMENTS OF CHANGES IN COMMON EQUITY
For the Six Months Ended June 30, 2021 and 2020
(Unaudited)
			Common Equity
			Common Stock						Retained Earnings						Total
			(In Thousands)
Balance at December 31, 2019			$601,850						$110,218						$712,068
Net income			—						28,513						28,513
Common stock dividends and distributions			—						(13,653)						(13,653)
Balance at March 31, 2020			601,850						125,078						726,928
Net income			—						28,991						28,991
Common stock dividends and distributions			—						(46,000)						(46,000)
Balance at June 30, 2020			$601,850						$108,069						$709,919
Balance at December 31, 2020			$951,850						$128,696						$1,080,546
Net income			—						23,864						23,864
Common stock dividends and distributions			—						(21,000)						(21,000)
Balance at March 31, 2021			951,850						131,560						1,083,410
Net income			—						30,330						30,330
Common stock dividends and distributions			—						(5,000)						(5,000)
Balance at June 30, 2021			$951,850						$156,890						$1,108,740
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES

PART II. OTHER INFORMATION

Item 1.  Legal Proceedings

See “PART I, Item 1, Litigation” in the Form 10-K for a discussion of legal, administrative, and other regulatory proceedings affecting Entergy.  Also see Notes 1 and 2 to the financial statements herein and “Item 5, Other Information, Environmental Regulation” below for updates regarding environmental proceedings and regulation.

Item 1A.  Risk Factors

See the risk factors discussed in “Part I, Item 1A. Risk Factors” in the Form 10-K, which could materially affect Entergy’s and its Registrant Subsidiaries’ business, financial condition, or future results. The information set forth in this report, including the risk factor presented below, updates and should be read in conjunction with the risk factors and information disclosed in the Form 10-K. In addition, because Entergy cannot predict the ultimate impacts of COVID-19, the actual impacts may also exacerbate other risks discussed in “Item 1A. Risk Factors” in the Form 10-K, any of which could have a material effect on Entergy and its Registrant Subsidiaries.

The impacts of the COVID-19 pandemic and responsive measures taken on Entergy’s and its Utility operating companies’ business, results of operations, and financial condition are highly uncertain and cannot be predicted.

In December 2019 a novel strain of coronavirus was reported to have surfaced in Wuhan, China. Since then, several variants of the COVID-19 virus have spread throughout the world, including the United States. To mitigate the spread of COVID-19, public health officials in the United States have both recommended and mandated wearing of masks and other precautions, including prohibitions on congregating in heavily-populated areas, mandated closure or limitations on the functions of non-essential business, and shelter-in-place orders or similar measures, including throughout Entergy’s service areas. While most of these mitigation measures have been lifted following the wide availability of COVID-19 vaccines, there is a risk that certain of these measures could be reinstated and/or continued, particularly given the recent spread within the Entergy service areas of the delta variant of COVID-19, and that such measures could have an adverse effect on the general economy, Entergy’s customers, and its operations.

Entergy and its Utility operating companies experienced a decline in commercial and industrial sales and an increase in arrearages and bad debt expense due to non-payment by customers, and while much of the commercial and industrial sales have recovered, such increased arrearages and bad debt expense are expected to continue, the extent and duration of which management cannot predict. The Utility operating companies have resumed disconnecting customers for non-payment of bills, but such disconnects could again be suspended at the Utility operating companies should another shelter-in-place order or similar measure occur and their regulators mandate. While they are working with regulators to ensure ultimate recovery for those and other COVID-19 related costs, the amount, method, and timing of such recovery is unknown. Entergy and its Registrant Subsidiaries also could experience, and in some cases have experienced, among other challenges, supply chain, vendor, and contractor disruptions; delays in completion of capital or other construction projects, maintenance, and other operations activities, including prolonged or delayed outages; delays in regulatory proceedings; workforce availability, health or safety issues; increased storm recovery costs; increased cybersecurity risks as a result of many employees telecommuting; volatility in the credit or capital markets (and any related increased cost of capital or any inability to access the capital markets or draw on available credit facilities); or other adverse impacts on their ability to execute on business strategies and initiatives.

Although the economy has been recovering, another economic decline could adversely impact Entergy’s and the Utility operating companies’ liquidity and cash flows, including through declining sales, reduced revenues, delays in receipts of customer payments, or increased bad debt expense. The Utility operating companies also may experience regulatory outcomes that require them to postpone planned investment and otherwise reduce costs due to the impact of the COVID-19 pandemic on their customers. In addition, if the COVID-19 pandemic creates additional disruptions or turmoil in the credit or financial markets, or adversely impacts Entergy’s credit metrics or ratings, such developments could adversely affect its ability to access capital on favorable terms and continue to

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meet its liquidity needs or cause a decrease in the value of its defined benefit pension trust funds, as well as its nuclear decommissioning trust funds, all of which are highly uncertain and cannot be predicted.

Entergy cannot predict the extent or duration of the outbreak, the impact of new variants of COVID-19, the timing, availability, distribution or effectiveness of a vaccine, anti-viral or other treatments for COVID-19, governmental responsive measures, or the extent of the effects or ultimate impacts on the global, national or local economy, the capital markets, or its customers, suppliers, operations, financial condition, results of operations, or cash flows.

Item 2.  Unregistered Sales of Equity Securities and Use of Proceeds

Issuer Purchases of Equity Securities (a)

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 (b)
4/01/2021-4/30/2021						—						$—						—						$350,052,918
5/01/2021-5/31/2021						—						$—						—						$350,052,918
6/01/2021-6/30/2021						—						$—						—						$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 addition to this authority, the Board has authorized share repurchase programs to enable opportunistic purchases in response to market conditions. In October 2010 the Board granted authority for a $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.  In addition, in the first quarter 2021, Entergy withheld 81,434 shares of its common stock at $95.12 per share, 40,476 shares of its common stock at $95.15 per share, 36,804 shares of its common stock at $94.75 per share, 36,347 shares of its common stock at $95.33 per share, 1,188 shares of its common stock at $91.16 per share, 853 shares of its common stock at $96.47 per share, 719 shares of its common stock at $98.01 per share, 678 shares of its common stock at $92.70 per share, 584 shares of its common stock at $94.69 per share, 118 shares of its common stock at $95 per share, and 10 shares of its common stock at $95.25 per share to pay income taxes due upon vesting of restricted stock granted and payout of performance units as part of its long-term incentive program.

(a)See Note 12 to the financial statements in the Form 10-K for additional discussion of the stock-based compensation plans.

(b)Maximum amount of shares that may yet be repurchased relates only to the $500 million plan and 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.

Item 5.  Other Information

Regulation of the Nuclear Power Industry

Following is an update to the “Regulation of the Nuclear Power Industry” section of Part I, Item 1 of the Form 10-K.

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Nuclear Waste Policy Act of 1982

Nuclear Plant Decommissioning

In March 2021 filings with the NRC were made reporting on decommissioning funding for all of Entergy subsidiaries’ nuclear plants.  Those reports showed that decommissioning funding for each of the nuclear plants met the NRC’s financial assurance requirements.

NRC Reactor Oversight Process

In March 2021 the NRC placed Grand Gulf in Column 3 based on the incidence of five unplanned plant scrams during calendar year 2020, some of which were related to upgrades made to the plant’s turbine control system during the spring 2020 refueling outage. The NRC plans to conduct a supplemental inspection of Grand Gulf in accordance with its inspection procedures for nuclear plants in Column 3.

Environmental Regulation

Following are updates to the “Environmental Regulation” section of Part I, Item 1 of the Form 10-K.

Clean Air Act and Subsequent Amendments

See the Form 10-K for discussion of the Clean Air Act and Subsequent Amendments set by the EPA in accordance with the Clean Air Act. Following are updates to that discussion.

New Source Review

As discussed in the Form 10-K, in January and February 2018, Entergy Arkansas, Entergy Mississippi, Entergy Power, and other co-owners received 60-day notice of intent to sue letters from the Sierra Club and the National Parks Conservation Association concerning allegations of violations of new source review and permitting provisions of the Clean Air Act at the Independence and White Bluff coal-burning units, respectively. In November 2018, following extensive negotiations, Entergy Arkansas, Entergy Mississippi, and Entergy Power entered a proposed settlement resolving those claims as well as other issues facing Entergy Arkansas’s fossil generation plants. The settlement, which formally resolves a complaint filed by the Sierra Club and the National Parks Conservation Association, was subject to approval by the U.S. District Court for the Eastern District of Arkansas. In March 2021 the District Court approved and entered the proposed settlement. For further information about the settlement, see “Regional Haze” discussed below.

National Ambient Air Quality Standards

See the Form 10-K for discussion of the National Ambient Air Quality Standards (NAAQS) set by the EPA in accordance with the Clean Air Act. Following are updates to that discussion.

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Hazardous Air Pollutants

The EPA released the final Mercury and Air Toxics Standard (MATS) rule in December 2011, which had a compliance date, with a widely granted one-year extension, of April 2016. The required controls have been installed and are operational at all affected Entergy units. In May 2020 the EPA finalized a rule that finds that it is not “appropriate and necessary” to regulate hazardous air pollutants from electric steam generating units under the provisions of section 112(n) of the Clean Air Act. This is a reversal of the EPA’s previous finding requiring such regulation. The final appropriate and necessary finding does not revise the underlying MATS rule. Several lawsuits have been filed challenging the appropriate and necessary finding. In February 2021 the D.C. Circuit granted the EPA’s motion to hold the litigation in abeyance pending the agency’s review of the appropriate and necessary rule. The EPA must file status reports with the court every 120 days. Entergy will continue to monitor this situation.

Cross-State Air Pollution

As discussed in the Form 10-K, the Cross-State Air Pollution Rule (CSAPR) has been remanded to and modified by the EPA on multiple occasions. In September 2016 the EPA finalized the CSAPR Update Rule to address interstate transport for the 2008 ozone NAAQS. In September 2019 the D.C. Circuit upheld the EPA’s underlying approach to the Update Rule, but determined that it was inconsistent with the Clean Air Act because it failed to include deadlines consistent with the downward states’ deadlines for attainment. The court remanded the rule to the EPA for further consideration, but did not vacate it so the rule remains in effect pending the EPA’s further review. In April 2021, addressing the D.C. Circuit’s remand, the EPA finalized revisions to the Update Rule, which became effective June 29, 2021. The rule finalizes interstate transport obligations for 21 states. For 12 states, including Louisiana, the EPA further reduced the number of NOx emission allowances allocated to each state. Entergy is currently analyzing the potential impact on its facilities in Louisiana. Preliminary analysis indicates that ozone season NOx allowances may become more expensive in Louisiana, which could impact the cost of dispatching Entergy’s generating units located in Louisiana.

Regional Haze

As discussed in the Form 10-K, in January and February 2018, Entergy Arkansas, Entergy Mississippi, Entergy Power, and other co-owners received 60-day notice of intent to sue letters from the Sierra Club and the National Parks Conservation Association concerning allegations of violations of new source review and permitting provisions of the Clean Air Act at the Independence and White Bluff coal-burning units, respectively. In November 2018, following extensive negotiations, Entergy Arkansas, Entergy Mississippi, and Entergy Power entered a proposed settlement resolving those claims and reducing the risk that Entergy Arkansas, as operator of Independence and White Bluff, might be compelled under the Clean Air Act’s regional haze program to install costly emissions control technologies. Consistent with the terms of the settlement and in many cases also the Part II state implementation plan (SIP), Entergy Arkansas, along with co-owners, agreed to begin using only low-sulfur coal at Independence and White Bluff by mid-2021; agreed to cease using coal at White Bluff and Independence by the end of 2028 and 2030, respectively; agreed to cease operation of the remaining gas unit at Lake Catherine by the end of 2027; reserved the option to develop new generating sources at each plant site; and committed to installing or proposing to regulators at least 800 MWs of renewable generation by the end of 2027, with at least half installed or proposed by the end of 2022 (which includes two existing Entergy Arkansas projects) and with all qualifying co-owner projects counting toward satisfaction of the obligation. Under the settlement, the Sierra Club and the National Parks Conservation Association also waived certain potential existing claims under federal and state environmental law with respect to specified generating plants. The settlement, which formally resolves a complaint filed by the Sierra Club and the National Parks Conservation Association, was subject to approval by the U.S. District Court for the Eastern District of Arkansas. In November 2020 the court denied motions by the Arkansas Attorney General and the Arkansas Affordable Energy Coalition to intervene and to stay the proceedings. The proposed intervenors did not appeal the ruling. The District Court approved and entered the proposed settlement in March 2021. Entergy met the settlement deadline to use low-sulfur coal, is on target to meet the other requirements of the settlement, and is in compliance with other SIP requirements.

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The second planning period (2018-2028) for the regional haze program requires states to examine sources for impacts on visibility and to prepare SIPs by July 31, 2021. Entergy has received information collection requests from Arkansas and Louisiana requesting an evaluation of technical and economic feasibility of various NOx and SO2 control technologies for Independence, Nelson 6, and Ninemile. Responses to the information requests have been submitted to the respective state agencies. Louisiana has issued its draft SIP which does not propose any additional air emissions controls for Entergy units in Louisiana. However, some public commenters believe additional air controls are cost-effective. It is not yet clear how the Louisiana Department of Environmental Quality (LDEQ) will respond in its final SIP, and the agency, like many other state agencies, did not meet the July 31, 2021 deadline to submit a SIP to the EPA for review. The LDEQ is now expected to finalize its Regional Haze SIP in late 2021 or early 2022.

New and Existing Source Performance Standards for Greenhouse Gas Emissions

As discussed in the Form 10-K, in January 2021 the U.S. Court of Appeals for the D.C. Circuit vacated the Affordable Clean Energy Rule (ACE). The court held that ACE relied on an incorrect interpretation of the Clean Air Act that the statute expressly forecloses emission reduction approaches, such as emissions trading and generating shifting, that cannot be applied at and to the individual source. The court remanded ACE to the EPA for further consideration and also vacated the repeal of the Clean Power Plan. In March 2021 the D.C. Circuit issued a partial mandate vacating the ACE rule, but withheld the mandate vacating the repeal of the Clean Power Plan pending the EPA’s new rulemaking to regulate greenhouse gas emissions. Thus, the Clean Power Plan will not take effect during the rulemaking process and there currently is no regulation in place with respect to greenhouse gas emissions from electric generating units and states are not expected to take further action to develop and submit plans at this time.

Coal Combustion Residuals

As discussed in the Form 10-K, in late 2017, Entergy determined that certain in-ground wastewater treatment system recycle ponds at its White Bluff and Independence facilities require management under the new EPA regulations. Each site has commenced closure of its two recycle ponds (four ponds total), prior to the April 11, 2021 deadline under the finalized CCR rule for unlined recycle ponds.

Other Environmental Matters

Entergy Texas

As discussed in the Form 10-K, due to COVID-19 pandemic delays, the Texas Commission on Environmental Quality (TCEQ) extended the Affected Property Assessment Report (APAR) and Ecological Risk Assessment submittal dates to December 2020, which Entergy timely met. Following the TCEQ’s review of the APAR and Ecological Risk Assessment, the TCEQ issued a No Further Action determination for the site in March 2021.

Item 6.  Exhibits

			3(a) -			Restated Certificate of Incorporation of Entergy Corporation, dated May 10, 2021 (3.1(i) to Form 8-K filed May 10, 2021 in 1-11299).
			4(a) -			Third Amended and Restated Credit Agreement dated as of June 3, 2021, among Entergy Corporation, as Borrower, the banks and other financial institutions listed on the signature pages thereof, as Lenders, Citibank, N.A., as Administrative Agent and LC Issuing Bank, MUFG Bank, Ltd., as LC Issuing Bank, and the other LC Issuing Banks from time to time parties thereto (4.1 to Form 8-K filed June 3, 2021 in 1-11299).

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			4(b) -			Third Amended and Restated Credit Agreement dated as of June 3, 2021, among Entergy Arkansas, LLC, as Borrower, the banks and other financial institutions listed on the signature pages thereof, as Lenders, Citibank, N.A., as Administrative Agent, JPMorgan Chase Bank, N.A., as LC Issuing Bank, and the other LC Issuing Banks from time to time parties thereto (4.2 to Form 8-K filed June 3, 2021 in 1-10764).
			4(c) -			Third Amended and Restated Credit Agreement dated as of June 3, 2021, among Entergy Louisiana, LLC, as Borrower, the banks and other financial institutions listed on the signature pages thereof, as Lenders, Citibank, N.A., as Administrative Agent, Wells Fargo Bank, National Association and BNP Paribas, as LC Issuing Banks, and the other LC Issuing Banks from time to time parties thereto (4.3 to Form 8-K filed June 3, 2021 in 1-32718).
			4(d) -			Third Amended and Restated Credit Agreement dated as of June 3, 2021, among Entergy Texas, Inc., as Borrower, the banks and other financial institutions listed on the signature pages thereof, as Lenders, Citibank, N.A., as Administrative Agent, JPMorgan Chase Bank, N.A., BNP Paribas, Mizuho Bank, Ltd. and The Bank of Nova Scotia, as LC Issuing Banks, and the other LC Issuing Banks from time to time parties thereto (4.4 to Form 8-K filed June 3, 2021 in 1-34360).
			4(e) -			Third Amended and Restated Credit Agreement dated as of June 22, 2021, among Entergy New Orleans, LLC, as Borrower, the banks and other financial institutions listed on the signature pages thereof, as Lenders, Bank of America, N.A., as Administrative Agent and LC Issuing Bank, and the other LC Issuing Banks from time to time parties thereto (4 to Form 8-K filed June 22, 2021 in 1-35747).
			4(f) -			Officer’s Certificate No. 2-B-2 for System Energy Resources, Inc. relating to First Mortgage Bonds, MBFC Series due 2044 (4(a) to Form 8-K filed June 15, 2021 in 1-09067).
			4(g) -			Trust Indenture, dated as of June 1, 2021, between the Mississippi Business Finance Corporation and The Bank of New York Mellon, as Indenture Trustee, relating to the Revenue Refunding Bonds (System Energy Resources, Inc. Project) Series 2021 (4(c) to Form 8-K filed June 15, 2021 in 1-09067).
			4(h) -			Loan Agreement, dated as of June 1, 2021, between the Mississippi Business Finance Corporation and System Energy Resources, Inc. relating to the Revenue Refunding Bonds (System Energy Resources, Inc. Project) Series 2021 (4(d) to Form 8-K filed June 15, 2021 in 1-09067).
			10(a) -			Amendment to Retention Agreement effective May 7, 2021 between Leo. P. Denault and Entergy Corporation (99.1 to Form 8-K filed May 10, 2021 in 1-11299).
			10(b) -			Thirty-ninth Assignment of Availability Agreement, Consent and Agreement, dated as of June 15, 2021, among System Energy Resources, Inc., Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, Entergy New Orleans, LLC, The Bank of New York Mellon, as Mortgage Trustee and The Bank of New York Mellon, as Indenture Trustee (4(b) to Form 8-K filed June 15, 2001 in 1-09067).
			*10(c) -			Restricted Stock Units Agreement Under The Entergy Corporation 2019 Omnibus Incentive Plan by and between Marcus V. Brown and Entergy Corporation effective May 17, 2021.
			*31(a) -			Rule 13a-14(a)/15d-14(a) Certification for Entergy Corporation.
			*31(b) -			Rule 13a-14(a)/15d-14(a) Certification for Entergy Corporation.
			*31(c) -			Rule 13a-14(a)/15d-14(a) Certification for Entergy Arkansas.
			*31(d) -			Rule 13a-14(a)/15d-14(a) Certification for Entergy Arkansas.
			*31(e) -			Rule 13a-14(a)/15d-14(a) Certification for Entergy Louisiana.
			*31(f) -			Rule 13a-14(a)/15d-14(a) Certification for Entergy Louisiana.
			*31(g) -			Rule 13a-14(a)/15d-14(a) Certification for Entergy Mississippi.
			*31(h) -			Rule 13a-14(a)/15d-14(a) Certification for Entergy Mississippi.
			*31(i) -			Rule 13a-14(a)/15d-14(a) Certification for Entergy New Orleans.

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			*31(j) -			Rule 13a-14(a)/15d-14(a) Certification for Entergy New Orleans.
			*31(k) -			Rule 13a-14(a)/15d-14(a) Certification for Entergy Texas.
			*31(l) -			Rule 13a-14(a)/15d-14(a) Certification for Entergy Texas.
			*31(m) -			Rule 13a-14(a)/15d-14(a) Certification for System Energy.
			*31(n) -			Rule 13a-14(a)/15d-14(a) Certification for System Energy.
			**32(a) -			Section 1350 Certification for Entergy Corporation.
			**32(b) -			Section 1350 Certification for Entergy Corporation.
			**32(c) -			Section 1350 Certification for Entergy Arkansas.
			**32(d) -			Section 1350 Certification for Entergy Arkansas.
			**32(e) -			Section 1350 Certification for Entergy Louisiana.
			**32(f) -			Section 1350 Certification for Entergy Louisiana.
			**32(g) -			Section 1350 Certification for Entergy Mississippi.
			**32(h) -			Section 1350 Certification for Entergy Mississippi.
			**32(i) -			Section 1350 Certification for Entergy New Orleans.
			**32(j) -			Section 1350 Certification for Entergy New Orleans.
			**32(k) -			Section 1350 Certification for Entergy Texas.
			**32(l) -			Section 1350 Certification for Entergy Texas.
			**32(m) -			Section 1350 Certification for System Energy.
			**32(n) -			Section 1350 Certification for System Energy.
			*101 INS -			Inline XBRL Instance Document - The instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
			*101 SCH -			Inline XBRL Schema Document.
			*101 PRE -			Inline XBRL Presentation Linkbase Document.
			*101 LAB -			Inline XBRL Label Linkbase Document.
			*101 CAL -			Inline XBRL Calculation Linkbase Document.
			*101 DEF -			Inline XBRL Definition Linkbase Document.
			*104 -			Cover Page Interactive Data File (formatted in Inline XBRL and contained in Exhibits 101).

___________________________

Pursuant to Item 601(b)(4)(iii) of Regulation S-K, Entergy Corporation agrees to furnish to the Commission upon request any instrument with respect to long-term debt that is not registered or listed herein as an Exhibit because the total amount of securities authorized under such agreement does not exceed ten percent of the total assets of Entergy Corporation and its subsidiaries on a consolidated basis.

*			Filed herewith.
**			Furnished, not filed, herewith.

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SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, each registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.  The signature for each undersigned company shall be deemed to relate only to matters having reference to such company or its subsidiaries.

ENTERGY CORPORATION ENTERGY ARKANSAS, LLC ENTERGY LOUISIANA, LLC ENTERGY MISSISSIPPI, LLC ENTERGY NEW ORLEANS, LLC ENTERGY TEXAS, INC. SYSTEM ENERGY RESOURCES, INC.
/s/ Kimberly A. Fontan
Kimberly A. Fontan Senior Vice President and Chief Accounting Officer (For each Registrant and for each as Principal Accounting Officer)

Date:    August 6, 2021

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