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ENTERGY NEW ORLEANS, LLC - Quarter Report: 2013 September (Form 10-Q)

a06313.htm

 __________________________________________________________________________________________
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

FORM 10-Q

(Mark One)
 
X
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
   
 
For the Quarterly Period Ended September 30, 2013
 
                                            OR
 
TRANSITION REPORT PURSUANT TO SECTION 13
OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
   
 
For the transition period from ____________ to ____________

 
Commission
File Number
Registrant, State of Incorporation or Organization,
Address of Principal Executive Offices, Telephone
Number, and IRS Employer Identification No.
 
 
Commission
File Number
Registrant, State of Incorporation or Organization,
Address of Principal Executive Offices, Telephone
Number, and IRS Employer Identification No.
1-11299
ENTERGY CORPORATION
(a Delaware corporation)
639 Loyola Avenue
New Orleans, Louisiana 70113
Telephone (504) 576-4000
72-1229752
 
1-31508
ENTERGY MISSISSIPPI, INC.
(a Mississippi corporation)
308 East Pearl Street
Jackson, Mississippi 39201
Telephone (601) 368-5000
64-0205830
         
         
1-10764
ENTERGY ARKANSAS, INC.
(an Arkansas corporation)
425 West Capitol Avenue
Little Rock, Arkansas 72201
Telephone (501) 377-4000
71-0005900
 
0-05807
ENTERGY NEW ORLEANS, INC.
(a Louisiana corporation)
1600 Perdido Street
New Orleans, Louisiana 70112
Telephone (504) 670-3700
72-0273040
         
         
0-20371
ENTERGY GULF STATES LOUISIANA, L.L.C.
(a Louisiana limited liability company)
446 North Boulevard
Baton Rouge, Louisiana 70802
Telephone (800) 368-3749
74-0662730
 
1-34360
ENTERGY TEXAS, INC.
(a Texas corporation)
350 Pine Street
Beaumont, Texas 77701
Telephone (409) 981-2000
61-1435798
         
         
1-32718
ENTERGY LOUISIANA, LLC
(a Texas limited liability company)
446 North Boulevard
Baton Rouge, Louisiana 70802
Telephone (800) 368-3749
75-3206126
 
1-09067
SYSTEM ENERGY RESOURCES, INC.
(an Arkansas corporation)
Echelon One
1340 Echelon Parkway
Jackson, Mississippi 39213
Telephone (601) 368-5000
72-0752777
         

__________________________________________________________________________________________


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

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

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

 
Large
accelerated
filer
 
 
Accelerated
filer
 
Non-
accelerated
filer
 
Smaller
reporting
company
Entergy Corporation
Ö
           
Entergy Arkansas, Inc.
       
Ö
   
Entergy Gulf States Louisiana, L.L.C.
       
Ö
   
Entergy Louisiana, LLC
       
Ö
   
Entergy Mississippi, Inc.
       
Ö
   
Entergy New Orleans, Inc.
       
Ö
   
Entergy Texas, Inc.
       
Ö
   
System Energy Resources, Inc.
       
Ö
   

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

Common Stock Outstanding
 
Outstanding at October 31, 2013
Entergy Corporation
($0.01 par value)
178,319,275

Entergy Corporation, Entergy Arkansas, Inc., Entergy Gulf States Louisiana, L.L.C., Entergy Louisiana, LLC, Entergy Mississippi, Inc., Entergy New Orleans, Inc., Entergy Texas, Inc., and System Energy Resources, Inc. 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, 2012 and the Quarterly Reports on Form 10-Q for the quarters ended March 31, 2013 and June 30, 2013, filed by the individual registrants with the SEC, and should be read in conjunction therewith.


ENTERGY CORPORATION AND SUBSIDIARIES
INDEX TO QUARTERLY REPORT ON FORM 10-Q
September 30, 2013

 
Page Number
   
iii
v
Entergy Corporation and Subsidiaries
 
1
28
29
30
32
34
35
36
92
Entergy Arkansas, Inc. and Subsidiaries
 
93
103
105
106
108
109
Entergy Gulf States Louisiana, L.L.C.
 
110
119
120
121
122
124
125
Entergy Louisiana, LLC and Subsidiaries
 
126
135
136
137
138
140
141
Entergy Mississippi, Inc.
 
142
149
151
152
154
155


ENTERGY CORPORATION AND SUBSIDIARIES
INDEX TO QUARTERLY REPORT ON FORM 10-Q
September 30, 2013

 
Page Number
   
Entergy New Orleans, Inc.
 
156
162
163
164
166
167
Entergy Texas, Inc. and Subsidiaries
 
168
175
177
178
180
181
System Energy Resources, Inc.
 
182
186
187
188
190
Part II.  Other Information
 
191
191
191
192
194
197




FORWARD-LOOKING INFORMATION

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

Forward-looking statements involve a number of risks and uncertainties.  There are factors that could cause actual results to differ materially from those expressed or implied in the forward-looking statements, including those factors discussed or incorporated by reference in (a) Item 1A. Risk Factors in the Form 10-K, (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 negotiations, including various performance-based rate discussions, Entergy’s utility supply plan, and recovery of fuel and purchased power costs;
·  
the termination of Entergy Arkansas’s and Entergy Mississippi’s participation in the System Agreement in December 2013 and November 2015, respectively, the termination of Entergy Texas’s participation in the System Agreement after expiration of the recently proposed 60-month notice period or such other period as approved by the FERC, and the potential for other Entergy operating companies to terminate participation in the System Agreement by providing notice pursuant to the recently proposed 60-month notice period or such other period as approved by the FERC in its pending proceeding and/or by seeking an amendment to the System Agreement that would allow for an Entergy operating company to terminate its participation in less than 96 months;
·  
regulatory and operating challenges and uncertainties associated with the Utility operating companies’ proposal to move to the MISO RTO;
·  
risks associated with the proposed spin-off and subsequent merger of Entergy’s electric transmission business into a subsidiary of ITC Holdings Corp., including the risk that Entergy and the Utility operating companies may not be able to timely satisfy the conditions or obtain the approvals required to complete such transaction or such approvals may contain material restrictions or conditions, and the risk that if completed, the transaction may not achieve its anticipated results;
·  
changes in utility regulation, including the beginning or end of retail and wholesale competition, the ability to recover net utility assets and other potential stranded costs, and the application of more stringent transmission reliability requirements or market power criteria by the FERC;
·  
changes in regulation of nuclear generating facilities and nuclear materials and fuel, including with respect to the planned or potential shutdown of nuclear generating facilities owned or operated by the Entergy Wholesale Commodities business, and the effects of new or existing safety or environmental concerns regarding nuclear power plants and nuclear fuel;
·  
resolution of pending or future applications, and related regulatory proceedings and litigation, for license renewals or modifications of nuclear generating facilities;
·  
the performance of and deliverability of power from Entergy’s generation resources, including the capacity factors at its nuclear generating facilities;
·  
Entergy’s ability to develop and execute on a point of view regarding future prices of electricity, natural gas, and other energy-related commodities;
·  
prices for power generated by Entergy’s merchant generating facilities and the ability to hedge, meet credit support requirements for hedges, sell power forward, or otherwise reduce the market price risk associated with those facilities, including the Entergy Wholesale Commodities nuclear plants;


FORWARD-LOOKING INFORMATION (Concluded)

·  
the prices and availability of fuel and power Entergy must purchase for its Utility customers, and Entergy’s ability to meet credit support requirements for fuel and power supply contracts;
·  
volatility and changes in markets for electricity, natural gas, uranium, and other energy-related commodities;
·  
changes in law resulting from federal or state energy legislation or legislation subjecting energy derivatives used in hedging and risk management transactions to governmental regulation;
·  
changes in environmental, tax, and other laws, including requirements for reduced emissions of sulfur, nitrogen, carbon, greenhouse gases, mercury, and other regulated air emissions, and changes in costs of compliance with environmental and other laws and regulations;
·  
uncertainty regarding the establishment of interim or permanent sites for spent nuclear fuel and nuclear waste storage and disposal;
·  
variations in weather and the occurrence of hurricanes and other storms and disasters, including uncertainties associated with efforts to remediate the effects of hurricanes, ice storms, or other weather events and the recovery of costs associated with restoration, including accessing funded storm reserves, federal and local cost recovery mechanisms, securitization, and insurance;
·  
effects of climate change;
·  
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 and operation and maintenance costs;
·  
Entergy’s ability to purchase and sell assets at attractive prices and on other attractive terms;
·  
the economic climate, and particularly economic conditions in Entergy’s Utility service area and the Northeast United States and events that could influence economic conditions in those areas;
·  
the effects of Entergy’s strategies to reduce tax payments;
·  
changes in the financial markets, particularly those affecting the availability of capital and Entergy’s ability to refinance existing debt, execute share repurchase programs, and fund investments and acquisitions;
·  
actions of rating agencies, including changes in the ratings of debt and preferred stock, changes in general corporate ratings, and changes in the rating agencies’ ratings criteria;
·  
changes in inflation and interest rates;
·  
the effect of litigation and government investigations or proceedings;
·  
changes in technology, including with respect to new, developing, or alternative sources of generation;
·  
the potential effects of threatened or actual terrorism, cyber attacks or data security breaches, including increased security costs, and war or a catastrophic event such as a nuclear accident or a natural gas pipeline explosion;
·  
Entergy’s ability to attract and retain talented management and directors;
·  
changes in accounting standards and corporate governance;
·  
declines in the market prices of marketable securities and resulting funding requirements for Entergy’s defined benefit pension and other postretirement benefit plans;
·  
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 or cost to decommission nuclear plant sites;
·  
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;
·  
factors that could lead to impairment of long-lived assets; and
·  
the ability to successfully complete merger, acquisition, or divestiture plans, regulatory or other limitations imposed as a result of merger, acquisition, or divestiture, and the success of the business following a merger, acquisition, or divestiture.


DEFINITIONS

Certain abbreviations or acronyms used in the text and notes are defined below:
 
Abbreviation or Acronym
 
 
Term
AFUDC
Allowance for Funds Used During Construction
ALJ
Administrative Law Judge
ANO 1 and 2
Units 1 and 2 of Arkansas Nuclear One (nuclear), owned by Entergy Arkansas
APSC
Arkansas Public Service Commission
ASLB
Atomic Safety and Licensing Board, the board within the NRC that conducts hearings and performs other regulatory functions that the NRC authorizes
ASU
Accounting Standards Update issued by the FASB
Board
Board of Directors of Entergy Corporation
capacity factor
Actual plant output divided by maximum potential plant output for the period
City Council or Council
Council of the City of New Orleans, Louisiana
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 company formally created as part of the jurisdictional separation of Entergy Gulf States, Inc. and the successor company to Entergy Gulf States, Inc. for financial reporting purposes.  The term is also used to refer to the Louisiana jurisdictional business of Entergy Gulf States, Inc., as the context requires.
Entergy Texas
Entergy Texas, Inc., a company formally created as part of the jurisdictional separation of Entergy Gulf States, Inc.  The term is also used to refer to the Texas jurisdictional business of Entergy Gulf States, Inc., as the context requires.
Entergy Wholesale
Commodities (EWC)
Entergy’s non-utility business segment primarily comprised of the ownership and operation of six nuclear power plants, the ownership of interests in non-nuclear power plants, and the sale of the electric power produced by those plants to wholesale customers
 
EPA
United States Environmental Protection Agency
ERCOT
Electric Reliability Council of Texas
FASB
Financial Accounting Standards Board
FERC
Federal Energy Regulatory Commission
FitzPatrick
James A. FitzPatrick Nuclear Power Plant (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
Form 10-K
Annual Report on Form 10-K for the calendar year ended December 31, 2012 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
Indian Point 2
Unit 2 of Indian Point Energy Center (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
Indian Point 3
Unit 3 of Indian Point Energy Center (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
IRS
Internal Revenue Service
ISO
Independent System Operator


DEFINITIONS (Concluded)

Abbreviation or Acronym
 
Term
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)
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
NYPA
New York Power Authority
Palisades
Palisades Power Plant (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
Pilgrim
Pilgrim Nuclear Power Station (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
PPA
Purchased power agreement or power purchase agreement
PUCT
Public Utility Commission of Texas
Registrant Subsidiaries
Entergy Arkansas, Inc., Entergy Gulf States Louisiana, L.L.C., Entergy Louisiana, LLC, Entergy Mississippi, Inc., Entergy New Orleans, Inc., Entergy Texas, Inc., and System Energy Resources, Inc.
River Bend
River Bend Station (nuclear), owned by Entergy Gulf States Louisiana
RTO
Regional transmission organization
SEC
Securities and Exchange Commission
SMEPA
South Mississippi Electric Power Association, which owns a 10% interest in Grand Gulf
System Agreement
Agreement, effective January 1, 1983, as modified, among the Utility operating companies relating to the sharing of generating capacity and other power resources
System Energy
System Energy Resources, Inc.
TWh
Terawatt-hour(s), which equals one billion kilowatt-hours
Unit Power Sales Agreement
Agreement, dated as of June 10, 1982, as amended and approved by FERC, among Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy, relating to the sale of capacity and energy from System Energy’s share of Grand Gulf
Utility
Entergy’s business segment that generates, transmits, distributes, and sells electric power, with a small amount of natural gas distribution
Utility operating companies
Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas
Vermont Yankee
Vermont Yankee Nuclear Power Station (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
Waterford 3
Unit No. 3 (nuclear) of the Waterford Steam Electric Station, 100% owned or leased by Entergy Louisiana
weather-adjusted usage
Electric usage excluding the effects of deviations from normal weather




ENTERGY CORPORATION AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS


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

·  
The Utility business segment includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operates a small natural gas distribution business.  As discussed in more detail in “Plan to Spin Off the Utility’s Transmission Business,” herein and in the Form 10-K, in December 2011, Entergy entered into an agreement to spin off its transmission business and merge it with a newly-formed subsidiary of ITC Holdings Corp.
·  
The Entergy Wholesale Commodities business segment includes the ownership and operation of six nuclear power plants located in the northern United States and the sale of the electric power produced by those plants to wholesale customers.  In August 2013, Entergy announced plans to close and decommission Vermont Yankee.  The plant is expected to cease power production in the fourth quarter 2014 after its current fuel cycle.  This business also provides services to other nuclear power plant owners.  Entergy Wholesale Commodities also owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.

Results of Operations

Third Quarter 2013 Compared to Third Quarter 2012

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the third quarter 2013 to the third quarter 2012 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)
                 
3rd Quarter 2012 Consolidated Net Income (Loss)
 
$300,506 
 
$86,772 
 
($44,608)
 
$342,670 
                 
Net revenue (operating revenue less fuel
  expense, purchased power, and other
  regulatory charges/credits)
 
 
 
120,042 
 
 
 
(607)
 
 
 
1,756 
 
 
 
121,191 
Other operation and maintenance expenses
 
50,999 
 
19,157 
 
3,950 
 
74,106 
Asset impairment
 
 
291,505 
 
 
291,505 
Taxes other than income taxes
 
3,186 
 
4,529 
 
186 
 
7,901 
Depreciation and amortization
 
17,907 
 
25,540 
 
(38)
 
43,409 
Other income
 
(4,093)
 
1,491 
 
1,376 
 
(1,226)
Interest expense
 
5,300 
 
1,150 
 
(3,196)
 
3,254 
Other expenses
 
3,612 
 
2,616 
 
 
6,228 
Income taxes
 
(16,852)
 
(164,013)
 
(27,085)
 
(207,950)
                 
3rd Quarter 2013 Consolidated Net Income (Loss)
 
$352,303 
 
($92,828)
 
($15,293)
 
$244,182 

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

Refer to "ENTERGY CORPORATION AND SUBSIDIARIES - SELECTED OPERATING RESULTS" for further information with respect to operating statistics.

 
1

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis


In the fourth quarter 2012, Entergy moved two subsidiaries from Parent & Other to the Entergy Wholesale Commodities segment to improve the alignment of certain intercompany items and income tax activity.  The prior period financial information in this Form 10-Q has been restated to reflect this change.

As discussed in more detail in Note 11 to the financial statements, third quarter 2013 results of operations includes $291.5 million ($183.7 million after-tax) of impairment and other related charges to write down the carrying value of Vermont Yankee and related assets to their fair values.

Net Revenue

Utility

Following is an analysis of the change in net revenue comparing the third quarter 2013 to the third quarter 2012:

  
 
Amount
  
 
(In Millions)
     
2012 net revenue
 
$1,508 
Retail electric price
 
67 
Fuel recovery
 
15 
Volume/weather
 
10 
Decommissioning trust
 
Net wholesale revenue
 
Hurricane Rita regulatory asset adjustment
 
Grand Gulf recovery
 
Other
 
2013 net revenue
 
$1,628 

The retail electric price variance is primarily due to:

·  
a formula rate plan increase at Entergy Louisiana, effective January 2013, which includes an increase relating to the Waterford 3 steam generator replacement project, which was placed in service in December 2012.  The net income effect of the formula rate plan increase is limited to a portion representing an allowed return on equity with the remainder offset by costs included in other operation and maintenance expenses, depreciation expenses, and taxes other than income taxes;
·  
the recovery of Hinds plant costs through the power management rider at Entergy Mississippi, as approved by the MPSC, effective with the first billing cycle of 2013.  The net income effect of the Hinds plant cost recovery is limited to a portion representing an allowed return on equity on the net plant investment with the remainder offset by the Hinds plant costs in other operation and maintenance expenses, depreciation expenses, and taxes other than income taxes;
·  
an increase in the capacity acquisition rider at Entergy Arkansas, as approved by the APSC, effective with the first billing cycle of December 2012, relating to the Hot Spring plant acquisition.  The net income effect of the Hot Spring plant cost recovery is limited to a portion representing an allowed return on equity on the net plant investment with the remainder offset by the Hot Spring plant costs in other operation and maintenance expenses, depreciation expenses, and taxes other than income taxes; and
·  
an increase in the energy efficiency rider, as approved by the APSC, effective July 2013.  Energy efficiency revenues are offset by costs included in other operation and maintenance expenses and have no effect on net income.

These increases are partially offset by a temporary increase in 2012 in the storm cost recovery rider at Entergy Mississippi, as approved by the MPSC for a five-month period effective August 2012.  The increase in revenues in 2012 was offset by costs included in other operation and maintenance expenses and had no effect on net income.  See Note 2 to the financial statements herein and in the Form 10-K for a discussion of rate proceedings.
 
 
2

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis


The fuel recovery variance is primarily due to:

·  
an adjustment to deferred fuel costs recorded in the third quarter 2012 in accordance with a rate order from the PUCT issued in September 2012.  See Note 2 to the financial statements in the Form 10-K for further discussion of this PUCT rate order;
·  
the expiration of the Evangeline gas contract on January 1, 2013; and
·  
the deferral of increased capacity costs that will be recovered through fuel adjustment clauses.

The volume/weather variance is primarily due to an increase of 342 GWh, or 1%, in weather-adjusted usage primarily in the industrial sector and an increase in sales volume in the unbilled sales period.  This was partially offset by the effect of less favorable weather on residential and commercial sales in the third quarter 2013 as compared to the same period in the prior year.  The increase in industrial sales was primarily due to growth in the chemicals and refining segments.

The decommissioning trust variance is primarily due to lower regulatory charges resulting from a decrease in interest earned on ANO and River Bend decommissioning trust investments in 2013 in accordance with regulatory treatment.  There is no effect on net income as this interest is reflected in other income.

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

The Hurricane Rita regulatory asset adjustment was recorded in third quarter 2012 in accordance with the rate order from the PUCT issued in September 2012.  See Note 2 to the financial statements in the Form 10-K for further discussion of the PUCT rate order.

The Grand Gulf recovery variance is primarily due to increased recovery of higher costs resulting from the Grand Gulf uprate.

Entergy Wholesale Commodities

Following is an analysis of the change in net revenue comparing the third quarter 2013 to the third quarter 2012:

  
 
Amount
  
 
(In Millions)
     
2012 net revenue
 
$495 
Nuclear realized price changes
 
(2)
Nuclear volume
 
Other
 
(4)
2013 net revenue
 
$494 

As shown in the table above, net revenue for Entergy Wholesale Commodities decreased by $1 million in the third quarter 2013 compared to the third quarter 2012 primarily due to:

·  
lower energy prices, substantially offset by higher capacity prices;
·  
the exercise of resupply options in the third quarter 2012 provided for in purchase power agreements whereby Entergy Wholesale Commodities may elect to supply power from another source when the plant is not running.  Amounts related to the exercise of resupply options are included in the GWh billed in the table below; and
·  
higher volume in its nuclear fleet resulting from fewer unplanned and refueling outage days in 2013 as compared to the same period in 2012.


 
3

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis


Following are key performance measures for Entergy Wholesale Commodities for the third quarter 2013 and 2012:

   
2013
 
2012
         
Owned capacity
 
6,612
 
6,612
GWh billed
 
11,630
 
12,002
Average realized revenue per MWh
 
$53.22
 
$51.88
         
Entergy Wholesale Commodities Nuclear Fleet
Capacity factor
 
94%
 
90%
GWh billed
 
10,274
 
10,480
Average realized revenue per MWh
 
$53.16
 
$52.27
Refueling outage days:
       
FitzPatrick
 
-
 
15

Realized Revenue per MWh Trend for Entergy Wholesale Commodities Nuclear Plants

The economic downturn and negative trends in the energy commodity markets have resulted over the past few years in lower natural gas prices and lower market prices for electricity in the New York and New England power regions, which is where five of the six Entergy Wholesale Commodities nuclear power plants are located.  Entergy Wholesale Commodities’s nuclear business experienced a decrease in realized price per MWh to $50.29 in 2012 from $54.73 in 2011 and $59.16 in 2010.  These price trends present a challenging economic situation for the Entergy Wholesale Commodities plants.  The challenge is greater for some of these plants based on a variety of factors such as their market for both energy and capacity, their size, their contracted positions, and the investment required to maintain the safety and integrity of the plants.  If, in the future, economic conditions or regulatory activity no longer support the continued operation of a plant by Entergy it could adversely affect Entergy’s results of operations through impairment charges, increased depreciation rates, transitional costs, or accelerated decommissioning costs.

On August 27, 2013, Entergy announced its plan to close and decommission Vermont Yankee.  Vermont Yankee is expected to cease power production in the fourth quarter 2014 after its current fuel cycle.  This decision was approved by the Board in August 2013.  The decision to shut down the plant was primarily due to sustained low natural gas and wholesale energy prices, the high cost structure of the plant, and lack of a market structure that adequately compensates merchant nuclear plants for their environmental and fuel diversity benefits in the region in which the plant operates.  See Note 11 to the financial statements herein for discussion of related impairment charges recorded during the third quarter 2013.

Impairment of long-lived assets and nuclear decommissioning costs, and the factors that influence these items, are both discussed in detail in the Form 10-K in “Critical Accounting Estimates.”  See also the discussion below in “Entergy Wholesale Commodities Authorizations to Operate Its Nuclear Power Plants” regarding Entergy Wholesale Commodities nuclear plant operating license and related activity.



 
4

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis


Other Income Statement Items

Utility

Other operation and maintenance expenses increased from $519 million for the third quarter 2012 to $570 million for the third quarter 2013 primarily due to:

·  
an increase of $25 million in compensation and benefits costs primarily due to a decrease in the discount rates used to determine net periodic pension and other postretirement benefit costs and a settlement charge, recognized in September 2013, related to the payment of lump sum benefits out of the non-qualified pension plan.  See "MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates" in the Form 10-K and Note 6 to the financial statements herein for further discussion of benefits costs;
·  
an increase of $8 million in fossil-fueled generation expenses primarily due to the acquisitions of the Hot Spring plant by Entergy Arkansas and the Hinds plant by Entergy Mississippi in November 2012.  Costs related to the Hot Spring and Hinds plants are recovered through the capacity acquisition rider and power management rider, respectively, as previously discussed;
·  
an increase of $8 million resulting from implementation and severance costs in 2013 related to the human capital management strategic imperative.  See “Human Capital Management Strategic Imperative” below for further discussion;
·  
an increase of approximately $7 million as a result of the deferral or capitalization of storm restoration costs in the third quarter 2012 for Hurricane Isaac, which hit the Utility’s service area in August 2012; and
·  
an increase of $3 million in energy efficiency costs at Entergy Arkansas.  These costs are recovered through an energy efficiency rider and have no effect on net income.

These increases were partially offset by a temporary increase in 2012 of $10 million in storm damage accruals, as approved by the MPSC for a five-month period effective August 2012.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Hot Spring and Hinds plant acquisitions in 2012 and the completion of the Waterford 3 steam generator replacement project and the Grand Gulf uprate project in 2012. 

Entergy Wholesale Commodities

The asset impairment variance is due to $291.5 million ($183.7 million after-tax) of impairment and other related charges in the third quarter 2013 to write down the carrying value of Vermont Yankee and related assets to their fair values.  See Note 11 to the financial statements herein for further discussion of these charges.

Other operation and maintenance expenses increased from $245 million for the third quarter 2012 to $264 million for the third quarter 2013 primarily due to an increase of $23 million in compensation and benefits costs primarily due to a decrease in the discount rates used to determine net periodic pension and other postretirement benefit costs and a settlement charge, recognized in September 2013, related to the payment of lump sum benefits out of the non-qualified pension plan.  See "MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates" in the Form 10-K and Note 6 to the financial statements herein for further discussion of benefits costs.

Depreciation and amortization expenses increased primarily due to an adjustment in 2012 resulting from a final court decision in the Entergy Nuclear Indian Point 2 lawsuit against the U.S. Department of Energy related to spent nuclear fuel disposal. The effects of recording the proceeds from the judgment reduced the plant in service balances with a corresponding $19 million reduction to previously-recorded depreciation expense.


 
5

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis


Income Taxes

The effective income tax rate was 9.1% for the third quarter 2013.  The difference in the effective income tax rate for the third quarter 2013 versus the statutory rate of 35% was primarily due to lower state income taxes resulting from a state deferred tax adjustment and the reversal of a state valuation allowance.  Also contributing to the lower rate was the reversal of a portion of the provision for uncertain tax positions.

The effective income tax rate was 40.4% for the third quarter 2012. The difference in the effective income tax rate versus the statutory rate of 35% for the third quarter 2012 was primarily due to state income taxes.

Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the nine months ended September 30, 2013 to the nine months ended September 30, 2012 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)
                 
2012 Consolidated Net Income (Loss)
 
$676,244 
 
($18,420)
 
($91,311)
 
$566,513 
                 
Net revenue (operating revenue less fuel
  expense, purchased power, and other
  regulatory charges/credits)
 
 
 
456,728 
 
 
 
(20,372)
 
 
 
5,929 
 
 
 
442,285 
Other operation and maintenance expenses
 
145,648 
 
21,650 
 
10,745 
 
178,043 
Asset impairment
 
 
(64,019)
 
 
(64,019)
Taxes other than income taxes
 
21,246 
 
7,201 
 
158 
 
28,605 
Depreciation and amortization
 
60,986 
 
25,944 
 
(100)
 
86,830 
Other income
 
(12,213)
 
(1,547)
 
1,761 
 
(11,999)
Interest expense
 
22,078 
 
(3,687)
 
5,314 
 
23,705 
Other expenses
 
12,204 
 
48,149 
 
 
60,353 
Income taxes
 
177,903 
 
(76,395)
 
2,554 
 
104,062 
                 
2013 Consolidated Net Income (Loss)
 
$680,694 
 
$818 
 
($102,292)
 
$579,220 

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

Refer to "ENTERGY CORPORATION AND SUBSIDIARIES - SELECTED OPERATING RESULTS" for further information with respect to operating statistics.

In the fourth quarter 2012, Entergy moved two subsidiaries from Parent & Other to the Entergy Wholesale Commodities segment to improve the alignment of certain intercompany items and income tax activity.  The prior period financial information in this Form 10-Q has been restated to reflect this change.

As discussed in more detail in Note 11 to the financial statements herein and Note 1 to the financial statements in the Form 10-K, results of operations for the nine months ended September 30, 2013 and September 30, 2012 include $291.5 million ($183.7 million after-tax) and $355.5 million ($223.5 million after-tax), respectively, of impairment and other related charges to write down the carrying value of Vermont Yankee and related assets to their fair values.  Also, net income for Utility for the nine months ended September 30, 2012 was significantly affected by a settlement with the IRS related to the income tax treatment of the Louisiana Act 55 financing of the Hurricane Katrina and Hurricane Rita
 
 
6

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis


storm costs, which resulted in a reduction in income tax expense.  The net income effect was partially offset by a regulatory charge, which reduced net revenue in 2012, associated with the storm costs settlement to reflect the obligation to customers with respect to the settlement.  See Note 3 to the financial statements in the Form 10-K for additional discussion of the tax settlement and savings obligation.

Net Revenue

Utility

Following is an analysis of the change in net revenue comparing the nine months ended September 30, 2013 to the nine months ended September 30, 2012:

  
 
Amount
  
 
(In Millions)
     
2012 net revenue
 
$3,765 
Retail electric price
 
190 
Louisiana Act 55 financing savings obligation
 
167 
Grand Gulf recovery
 
70 
Fuel recovery
 
30 
MISO deferral
 
12 
Volume/weather
 
(7)
Other
 
(5)
2013 net revenue
 
$4,222 

The retail electric price variance is primarily due to:

·  
the recovery of Hinds plant costs through the power management rider at Entergy Mississippi, as approved by the MPSC, effective with the first billing cycle of 2013.  The net income effect of the Hinds plant cost recovery is limited to a portion representing an allowed return on equity on the net plant investment with the remainder offset by the Hinds plant costs in other operation and maintenance expenses, depreciation expenses, and taxes other than income taxes;
·  
a formula rate plan increase at Entergy Louisiana, effective January 2013, which includes an increase relating to the Waterford 3 steam generator replacement project, which was placed in service in December 2012.  The net income effect of the formula rate plan increase is limited to a portion representing an allowed return on equity with the remainder offset by costs included in other operation and maintenance expenses, depreciation expenses, and taxes other than income taxes;
·  
an increase in the capacity acquisition rider at Entergy Arkansas, as approved by the APSC, effective with the first billing cycle of December 2012, relating to the Hot Spring plant acquisition.  The net income effect of the Hot Spring plant cost recovery is limited to a portion representing an allowed return on equity on the net plant investment with the remainder offset by the Hot Spring plant costs in other operation and maintenance expenses, depreciation expenses, and taxes other than income taxes;
·  
an annual base rate increase at Entergy Texas, effective July 2012, as a result of the PUCT’s order in the November 2011 rate case that was issued in September 2012; and
·  
increases in the energy efficiency rider, as approved by the APSC, effective July 2013 and July 2012.  Energy efficiency revenues are offset by costs included in other operation and maintenance expenses and have no effect on net income.

These increases are partially offset by a temporary increase in 2012 in the storm cost recovery rider at Entergy Mississippi, as approved by the MPSC for a five-month period effective August 2012.  The increase in revenues in 2012 was offset by costs included in other operation and maintenance expenses and had no effect on net income.  See Note 2 to the financial statements herein and in the Form 10-K for a discussion of rate proceedings.



 
7

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis


The Louisiana Act 55 financing savings obligation variance results from a regulatory charge recorded in the second quarter 2012 because Entergy Gulf States Louisiana and Entergy Louisiana are sharing with customers the savings from an IRS settlement related to the uncertain tax position regarding the Hurricane Katrina and Hurricane Rita Louisiana Act 55 financing.  See Note 3 to the financial statements in the Form 10-K for additional discussion of the tax settlement and savings obligation.

The Grand Gulf recovery variance is primarily due to increased recovery of higher costs resulting from the Grand Gulf uprate.

The fuel recovery variance is primarily due to:

·  
an adjustment to deferred fuel costs recorded in the third quarter 2012 in accordance with a rate order from the PUCT issued in September 2012.  See Note 2 to the financial statements in the Form 10-K for further discussion of this PUCT rate order;
·  
the expiration of the Evangeline gas contract on January 1, 2013; and
·  
the deferral of increased capacity costs that will be recovered through fuel adjustment clauses.

The MISO deferral variance is primarily due to the deferral in April 2013, as approved by the APSC, of costs incurred since March 2010 related to the transition and implementation of joining the MISO RTO.

The volume/weather variance is primarily due to less favorable weather on residential and commercial sales for the nine months ended September 30, 2013 as compared to the same period in the prior year and a decrease of 154 GWh, or 0.2%, in weather-adjusted usage, partially offset by an increase in sales volume in the unbilled sales period.

Entergy Wholesale Commodities

Following is an analysis of the change in net revenue comparing the nine months ended September 30, 2013 to the nine months ended September 30, 2012:

  
 
Amount
  
 
(In Millions)
     
2012 net revenue
 
$1,391 
Nuclear volume
 
(50)
Mark-to-Market
 
(13)
Nuclear realized price changes
 
54 
Other
 
(12)
2013 net revenue
 
$1,370 

As shown in the table above, net revenue for Entergy Wholesale Commodities decreased by approximately $21 million in the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to:

·  
lower volume in its nuclear fleet resulting from more unplanned and refueling outage days in 2013 as compared to the same period in 2012;
·  
the exercise of resupply options provided for in purchase power agreements whereby Entergy Wholesale Commodities may elect to supply power from another source when the plant is not running.  Amounts related to the exercise of resupply options are included in the GWh billed in the table below; and
·  
the effect of lower power prices on electricity derivative instruments that are not designated as hedges.  See Note 8 to the financial statements herein for discussion of derivative instruments.

These decreases were substantially offset by higher capacity prices.

 
8

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis


Following are key performance measures for Entergy Wholesale Commodities for the nine months ended September 30, 2013 and 2012:

   
2013
 
2012
         
Owned capacity
 
6,612
 
6,612
GWh billed
 
33,189
 
34,957
Average realized revenue per MWh
 
$52.95
 
$49.84
         
Entergy Wholesale Commodities Nuclear Fleet
Capacity factor
 
86%
 
88%
GWh billed
 
29,309
 
30,744
Average realized revenue per MWh
 
$52.37
 
$50.42
Refueling outage days:
       
FitzPatrick
 
-
 
15
Indian Point 2
 
-
 
28
Indian Point 3
 
28
 
-
Palisades
 
-
 
34
Pilgrim
 
45
 
-
Vermont Yankee
 
27
 
-

Other Income Statement Items

Utility

Other operation and maintenance expenses increased from $1,531 million for the nine months ended September 30, 2012 to $1,677 million for the nine months ended September 30, 2013 primarily due to:

·  
an increase of $49 million in compensation and benefits costs primarily due to a decrease in the discount rates used to determine net periodic pension and other postretirement benefit costs and a settlement charge, recognized in September 2013, related to the payment of lump sum benefits out of the non-qualified pension plan.  See "MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates" in the Form 10-K and Note 6 to the financial statements herein for further discussion of benefits costs;
·  
an increase of $37 million in fossil-fueled generation expenses primarily due to the acquisitions of the Hot Spring plant by Entergy Arkansas and the Hinds plant by Entergy Mississippi in November 2012.  Costs related to the Hot Spring and Hinds plants are recovered through the capacity acquisition rider and power management rider, respectively, as previously discussed.  Also contributing to the increases is an overall higher scope of work done during plant outages as compared to the prior year;
·  
an increase of $17 million in nuclear expenses, primarily due to higher labor costs, including higher contract labor;
·  
an increase of $12 million in energy efficiency costs at Entergy Arkansas.  These costs are recovered through an energy efficiency rider and have no effect on net income;
·  
an increase of $11 million resulting from costs related to the generator stator incident at ANO, including an offset for expected insurance proceeds.  See “ANO Damage and Outage” below for further discussion of the ANO incident;
·  
the prior year deferral, as approved by the LPSC and the FERC, of costs related to the transition and implementation of joining the MISO RTO, which reduced 2012 expenses by $10 million; and
·  
an increase of $9 million resulting from implementation and severance costs in 2013 related to the human capital management strategic imperative.  See “Human Capital Management Strategic Imperative” below for further discussion.


 
9

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis


Taxes other than income taxes increased primarily due to an increase in ad valorem taxes, primarily due to the Hot Spring and Hinds plant acquisitions in 2012, as well as an increase in local franchise taxes resulting from higher residential and commercial revenues as compared with prior year.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the Hot Spring and Hinds plant acquisitions in 2012 and the completion of the Waterford 3 steam generator replacement project and the Grand Gulf uprate project in 2012.  Also contributing to the increase is an increase in depreciation rates as a result of the rate order approved by the PUCT in September 2012.

Interest expense increased primarily due to net debt issuances by certain of the Utility operating companies.  See Note 5 to the financial statements in the Form 10-K and Note 4 herein for more details of long-term debt activity.

Entergy Wholesale Commodities

Other operation and maintenance expenses increased from $726 million for the nine months ended September 30, 2012 to $748 million for the nine months ended September 30, 2013 primarily due to an increase of $29 million in compensation and benefits costs primarily due to a decrease in the discount rates used to determine net periodic pension and other postretirement benefit costs and a settlement charge, recognized in September 2013, related to the payment of lump sum benefits out of the non-qualified pension plan.  See "MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates" in the Form 10-K and Note 6 to the financial statements herein for further discussion of benefits costs.

Depreciation and amortization expenses increased primarily due to an adjustment in 2012 resulting from a final court decision in the Entergy Nuclear Indian Point 2 lawsuit against the U.S. Department of Energy related to spent nuclear fuel disposal. The effects of recording the proceeds from the judgment reduced the plant in service balances with a corresponding $19 million reduction to previously-recorded depreciation expense.

The asset impairment variance is due to impairment and other related charges of $355.5 million ($223.5 million after-tax) recorded in first quarter 2012 and $291.5 million ($183.7 million after-tax) recorded in third quarter 2013 to write down the carrying value of Vermont Yankee and related assets to their fair values.  See Note 1 to the financial statements in the Form 10-K and Note 11 to the financial statements herein for further discussion of these charges.

Other expenses increased primarily due to a credit to decommissioning expense of $49 million in the second quarter 2012 resulting from a reduction in the decommissioning cost liability for a plant as a result of a revised decommissioning cost study.  See “Critical Accounting Estimates – Nuclear Decommissioning Costs” in the Form 10-K for further discussion.

Income Taxes

The effective income tax rate was 27% for the nine months ended September 30, 2013.  The difference in the effective income tax rate for the nine months ended September 30, 2013 versus the statutory rate of 35% was primarily due to the reversal of a portion of the provision for uncertain tax positions, lower state income taxes resulting from a state deferred tax adjustment and the reversal of a state valuation allowance, and book and tax differences related to the allowance for equity funds used during construction, partially offset by certain book and tax differences related to utility plant items.  See Note 10 to the financial statements herein for further discussion of income taxes.

The effective income tax rate was 16.3% for the nine months ended September 30, 2012.  The difference in the effective income tax rate versus the statutory rate of 35% for the nine months ended September 30, 2012 was related to (1) an IRS settlement on how to treat the Louisiana Act 55 Financing of the Hurricane Katrina and Hurricane Rita storm costs, as discussed further in Note 3 to the financial statements in the Form 10-K; and (2) a unanimous court decision from the U.S. Court of Appeals for the Fifth Circuit affirming an earlier decision of the U.S. Tax Court holding that Entergy was entitled to claim a credit against its U.S. tax liability for the U.K. windfall tax that it paid, both of which enabled Entergy to reverse provisions for uncertain tax positions.  See Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein for further discussion of the settlement and tax credit.


 
10

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis


Plan to Spin Off the Utility’s Transmission Business

See the Form 10-K for a discussion of Entergy’s plan to spin off its transmission business and merge it with a newly formed subsidiary of ITC Holdings Corp.  On April 16, 2013, the ITC shareholders approved the ITC merger proposals.  On June 28, 2013, Entergy and ITC mutually agreed to extend the term of the Merger Agreement to December 31, 2013, after which it may be terminated by either party if the transaction has not been consummated.  The transaction is not expected to close in 2013, and a revised closing date in 2014 has not been settled upon.  Pursuant to the Merger Agreement, and subject to the terms and conditions set forth therein, Entergy will distribute the TransCo common units to its shareholders, excluding any TransCo common units contributed to an exchange trust if Entergy makes the exchange trust election.  At Entergy’s election, it may distribute the TransCo common units by means of a pro rata dividend in a spin-off or pursuant to an exchange offer in a split-off, or a combination of a split-off and a spin-off (the Distribution).  On July 24, 2013, Mid South TransCo LLC (TransCo) filed a registration statement with the SEC on Forms S-1/S-4 under which the Distribution would occur by means of a combination of a split-off and a spin-off.

Filings with Retail Regulators

See the Form 10-K for a discussion of the applications that each of the Utility operating companies has filed with their respective retail regulators seeking approval for the proposal to spin off and merge the transmission business with ITC.

In each retail jurisdiction, the Utility operating companies and ITC have offered certain commitments for consideration should the retail regulators deem it appropriate to impose conditions on the approval of the transaction, including a commitment to mitigate certain effects on customer rates for a period of at least five years.  In the offered commitments, the Utility operating companies and ITC proposed an initial five-year period of wholesale rebates and retail rate mitigation totaling $134.0 million for Entergy Arkansas customers, $48.6 million for Entergy Gulf States Louisiana customers, $59.5 million for Entergy Louisiana customers, $74.1 million for Entergy Mississippi customers, $20.0 million for Entergy New Orleans customers, and $69.6 million for Entergy Texas customers.  The share of the rate mitigation to be borne will vary by Utility operating company, but the Utility is expected to bear, on an aggregate basis, over the initial five-year period, approximately 65% to 70% of the wholesale rebates and retail rate mitigation, with ITC expected to bear the remainder.  At the end of the first five years following the close of the transaction, the economic and performance benefits of ITC’s ownership will be measured and verified by an independent auditor to determine if they offset the ownership cost increase resulting from ITC’s weighted average cost of capital.  If the benefits exceed such costs, rate mitigation will cease.  If they do not, wholesale rebates and retail rate mitigation will continue until the benefits exceed these costs.

The Utility operating companies have offered the following additional retail rate mitigation to address the effects of moving to a forward test year: $6.9 million for Entergy Arkansas customers, $5.4 million for Entergy Gulf States Louisiana customers, $7.2 million for Entergy Louisiana customers, $6.7 million for Entergy Mississippi customers, $0.4 million for Entergy New Orleans customers, and $13.1 million for Entergy Texas customers.  Lastly, Entergy Texas customers will also experience net avoided costs of $10.0 million due to the effects of eliminating transmission cost allocation under the Entergy System Agreement.  Entergy Gulf States Louisiana and Entergy Louisiana customers will also experience net avoided costs of $4.1 million and $12.2 million, respectively, due to the effects of both eliminating transmission cost allocation under the Entergy System Agreement and moving to MISO’s transmission pricing zone structure.

These proposed commitments may change as the regulatory proceedings progress.

In April 2013 the LPSC staff, APSC staff, and other parties filed testimony in the proceedings pending at the LPSC and APSC, respectively, identifying concerns with the proposed transaction and concluding that the transaction in its current form does not satisfy the applicable criteria for approval.  The LPSC staff testimony also included a comprehensive set of conditions should the LPSC determine that the transaction is in the public interest.  Conditions were also recommended by the Arkansas Attorney General should the APSC consider approving the transaction.  In April and May 2013 various parties and the PUCT staff respectively filed testimony in the PUCT proceeding identifying
 
 
11

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis


concerns with the proposed transaction and concluding that the transaction in its current form does not satisfy the applicable criteria for approval.  Certain parties also included a comprehensive set of conditions should the PUCT determine that the transaction is in the public interest.   In May 2013 the City Council advisors filed testimony identifying concerns with the proposed transaction and concluding that the transaction in its current form does not satisfy the applicable criteria for approval.  In June 2013 the Mississippi Public Utilities Staff and other parties filed testimony in the MPSC proceeding identifying concerns with the proposed transaction and concluding that the transaction in its current form does not satisfy the applicable criteria for approval.  The Mississippi Public Utilities Staff also included a comprehensive set of conditions should the MPSC determine that the transaction is in the public interest.

The PUCT hearing on the joint application was held before the ALJs in May 2013.  In July 2013 the ALJs issued a proposal for decision that recommended the denial of the joint application.  The ALJs further recommended that if the PUCT approved the joint application, the PUCT impose certain conditions on Entergy Texas and ITC.  Exceptions to the proposal for decision were filed in July 2013, and on August 9, 2013, the PUCT granted the applicants’ motion to withdraw the application with an opportunity to file a new application in the future that would include evidence not in the record considered by the ALJs.  In September 2013 the applicants filed their updated application with the PUCT, including a request for a decision by December 2013.  The PUCT has adopted a procedural schedule that sets a hearing on the merits for this matter before the Commissioners on November 21-22, 2013.  A final order is not expected until January 2014.

The APSC postponed a previously-scheduled July 9, 2013 hearing to allow the parties to pursue more details regarding the rate mitigation commitments described above.  In August 2013 in response to a motion to suspend the procedural schedule in light of the withdrawal of the application in Texas, the APSC issued an order cancelling a re-scheduled September 2013 evidentiary hearing and ordering the applicants to file monthly status reports (beginning in October 2013) regarding the applications in the other retail jurisdictions.  The order also provided that the parties should work together to establish a schedule that would permit the APSC to conduct the evidentiary hearing, deliberate and develop a final ruling, if reasonably possible, by the end of 2013.  Beginning on October 1, 2013, the applicants began filing the requested status reports.  The evidentiary hearing in Arkansas has not yet been re-scheduled.

LPSC hearings were held in July 2013.  At its July 31, 2013 meeting, the LPSC voted to allow a 45-day discovery period regarding the mitigation commitments offered by the Utility operating companies and ITC.  On August 21, 2013, the LPSC proceeding was suspended pending the LPSC’s receipt of notice that the applicants have filed a new application in Texas.  After providing notice of the filing of the updated application in Texas, a revised LPSC procedural schedule was set that calls for an additional round of testimony and briefing to conclude by November 8, 2013.

In the MPSC proceeding, the parties filed reply briefs and responses to proposed orders on September 25, 2013.  Entergy Mississippi and ITC also submitted filings on that day that indicated whether they would comply with conditions proposed by the Mississippi Public Utilities Staff.  There is no procedural deadline by which the MPSC must issue a decision in this matter.

On October 10, 2013, the City Council granted a motion to suspend the proceeding in light of the withdrawal and re-filing of the Texas application.  The City Council ordered the parties to develop a revised agreed procedural schedule within 14 days or submit proposed alternate schedules thereafter for consideration by the City Council. Pursuant to the City Council’s directive, the parties have agreed to a revised procedural schedule that provides for the advisors and intervenors to submit supplemental surrebuttal testimony on December 20, 2013, an evidentiary hearing (paper only), and supporting briefs by all parties to be filed on December 27, 2013.
 
 
12

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis


Because Entergy Arkansas also owns limited transmission facilities in Missouri, on February 14, 2013, Entergy Arkansas together with ITC and related parties filed an application out of an abundance of caution with the Missouri Public Service Commission pertaining to the ITC transaction.  On April 18, 2013, the Missouri Public Service Commission consolidated for purposes of a hearing Entergy Arkansas’s separate MISO case that is related to Entergy Arkansas’s notice of its intent to integrate into MISO with the Entergy and ITC case that is related to the proposal to spin off and merge the transmission business with ITC.  The hearing before the Missouri Public Service Commission took place in June 2013, and post-hearing briefs were filed in July and early August 2013.  The Missouri Public Service Commission has not issued an order in the ITC proceeding and has delayed further consideration of the matter pending procedural developments in the retail jurisdictions.

Filings with the FERC

See the Form 10-K for a discussion of the series of filings with the FERC made by Entergy, ITC, and certain of their subsidiaries to obtain regulatory approvals related to the proposed transfer to ITC subsidiaries of the transmission assets owned by the Utility operating companies.

On September 24, 2012, ITC and Entergy filed a joint application with the FERC seeking all necessary approvals under sections 203 and 205 of the Federal Power Act and the necessary declaration under section 305(a) of the Federal Power Act.   On June 20, 2013, the FERC issued an order authorizing the transactions under section 203 of the Federal Power Act, and also issued a declaration that section 305(a) of the Federal Power Act is not implicated by the transactions because the concerns underlying section 305(a) of the Federal Power Act are not present in the transactions. The FERC order also stated that the exchange trust election will not undermine or interfere with the independence of ITC.  The FERC order rejected, without prejudice, the request to extend by six months the deadline for new employees of ITC to dispose of their Entergy common stock.

The FERC issued a separate order on June 20, 2013, addressing the rate formula proposed by ITC in the September 24, 2012 application, as well as certain ancillary agreements also submitted for FERC’s approval with the application.  In that order, the FERC summarily approved certain aspects of ITC’s rate proposal, such as the 12.38% return on equity, a capital structure of 60% equity/40% debt, and use of a forward-looking formula rate.  However, the FERC found that other aspects of the rate proposal raised issues of material fact that cannot be resolved based on the record before the FERC, and thus ordered hearing and settlement judge procedures.  The FERC also accepted certain transaction-related agreements for filing, but included the transition services agreements and certain other ancillary agreements in the ordered hearing and settlement judge procedures.  The FERC consolidated the issues set for hearing and settlement judge procedures with two other Section 205 proceedings related to the transactions: (1) a proposed ratemaking treatment for certain pension and post-retirement welfare plan costs that relate to the Entergy employees that will become employees of ITC; and (2) the Attachment O formula rate templates filed by Entergy Services, on behalf of the Utility operating companies, on February 15, 2013, which includes the basis for the initial charges to be collected by the new operating subsidiaries of ITC post-closing, as well as the rates proposed to apply under the MISO Tariff in the event the transactions fail to close and Entergy retains its transmission assets.

On June 20, 2013, the FERC also issued an order accepting MISO’s proposed amendment to the MISO Tariff to enable the integration of the new ITC Operating Companies’ transmission facilities into MISO prior to the Utility operating companies becoming market participants in MISO.  In addition, on June 20, 2013, the FERC issued an order accepting Entergy Services’s application under the Federal Power Act section 205 to cancel System Agreement Service Schedule MSS-2 (Transmission Equalization) effective upon closing of the ITC transaction.

On July 22, 2013, various parties filed requests for rehearing of the FERC orders issued on June 20, 2013.  Settlement discussions are ongoing with respect to the matters the FERC set for hearing in the June 20, 2013 orders.
 
 
13

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis


In October 2012, Entergy, ITC, and certain subsidiaries submitted filings with the FERC to obtain regulatory approvals under Federal Power Act section 204 for the various financings being undertaken as part of the transaction.  On May 16, 2013, the FERC issued an order authorizing the proposed financings for the ITC Transaction under Federal Power Act section 204 subject to the closing of the transaction, including authorization until October 31, 2013, for the Utility operating companies to provide credit support in the form of guarantees of borrowings during the transaction.  The Utility operating companies will apply to FERC for renewal of that authority through 2014 to facilitate transaction closing.


Other Filings

In July 2012, Entergy Corporation submitted a request to the Internal Revenue Service seeking a private letter ruling substantially to the effect that certain requirements for the tax-free treatment of the distribution of the transmission business are met.  In May 2013, Entergy obtained IRS rulings regarding the tax-free treatment of certain aspects of the transactions.  While the May 2013 IRS rulings provide sufficient guidance for Entergy to execute the spin-merge in a tax-free manner, Entergy requested additional IRS rulings regarding certain other aspects of the transactions during the third quarter 2013.  In September 2012, Entergy submitted an application to the NRC for approval of certain nuclear plant license transfers and amendments as part of the steps to complete the spin-off and merger.  In May 2013 the NRC issued orders approving the license transfers and amendments.

On December 14, 2012, Entergy and ITC filed the required notifications under the Hart-Scott-Rodino Act with the Federal Trade Commission and the Department of Justice related to Entergy’s plan to spin off its transmission business and merge it with a newly formed subsidiary of ITC Holdings Corp.  The waiting period under the Hart-Scott-Rodino Act expired on January 14, 2013.  The ability to close the transaction based on the December 14, 2012 premerger notification filings expires on January 14, 2014, however, and Entergy and ITC are in the process of preparing new notifications to allow for a closing after January 14, 2014.

Entergy Wholesale Commodities Authorizations to Operate Its Nuclear Power Plants

See the Form 10-K for a discussion of the NRC operating licenses for Indian Point 2 and Indian Point 3 and the NRC license renewal applications in process for these plants.  Following are updates to the discussion regarding the NRC proceedings and related New York State proceedings.

The original expiration date of the NRC license for Indian Point Unit 2 was September 28, 2013.  Indian Point Unit 2 has now entered its “period of extended operation” after expiration of the plant’s initial license term under “timely renewal,” which is a federal statutory rule of general applicability providing for extension of a license for which a renewal application has been timely filed with the licensing agency. The Indian Point license renewal application qualifies for timely renewal protection because it met NRC regulatory standards for timely filing.

In August 2013, Riverkeeper filed with the ASLB a proposed amended Endangered Species Act contention alleging that NRC Staff’s supplemental Final Supplemental Environmental Impact Statement (FSEIS) issued in June 2013 did not document sufficient consultation between NRC Staff and the National Marine Fisheries Service regarding endangered species.  Entergy and NRC Staff have filed answers in opposition.  Riverkeeper’s proposed amended contention and Entergy’s motion to dismiss Riverkeeper’s original admitted contention on endangered species are pending before the ASLB.

Hearings were held in July 2013 before NYSDEC ALJs on environmental issues related to Indian Point’s wedgewire screen proposal for “best technology available.”  The ALJs have issued no partial decisions on the several issues that have been litigated during the past two years and have not announced a schedule for doing so.

The New York State Department of Environmental Conservation (NYSDEC) has taken the position that Indian Point must obtain a new state-issued Clean Water Act Section 401 water quality certification as part of the license renewal process.  Entergy submitted its application for a water quality certification to the NYSDEC in April 2009, with a reservation of rights regarding the applicability of Section 401 in this case.  After Entergy submitted certain additional information in response to NYSDEC requests, in February 2010 the NYSDEC staff determined that Entergy’s water quality certification application was complete.  In April 2010 the NYSDEC staff issued a proposed notice of denial of Entergy’s water quality certification application (the Notice).  NYSDEC staff’s Notice triggered an administrative adjudicatory hearing before NYSDEC ALJs on the proposed Notice.  The NYSDEC staff decision does not restrict Indian Point operations, but the issuance of a certification is potentially required prior to NRC issuance of renewed unit
 
 
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Management’s Financial Discussion and Analysis


licenses.  In June 2011, Entergy filed notice with the NRC that the NYSDEC, the agency that would issue or deny a water quality certification for the Indian Point license renewal process, has taken longer than one year to take final action on Entergy’s application for a water quality certification and, therefore, has waived its opportunity to require a certification under the provisions of Section 401 of the Clean Water Act.  The NYSDEC has notified the NRC that it disagrees with Entergy’s position and does not believe that it has waived the right to require a certification.  The NYSDEC ALJs overseeing the agency’s certification adjudicatory process stated in a ruling issued in July 2011 that while the waiver issue is pending before the NRC, the NYSDEC hearing process will continue on selected issues.  The judges held a Legislative Hearing (agency public comment session) and an Issues Conference (pre-trial conference) in July 2010.  Issue-by-issue hearings before the NYSDEC ALJs began in October 2011 and are expected to continue, on an episodic basis, into 2014 and perhaps longer.  After hearings and briefing on all issues, the ALJs will issue a recommended decision to the Commissioner or his delegate, who will then issue the final agency decision.  A party to the proceeding can appeal the decision of the Commissioner to state court.

In addition, the consistency of Indian Point’s operations with New York State’s coastal management policies must be resolved to the extent required by the Coastal Zone Management Act (CZMA).  Entergy has undertaken three independent initiatives to resolve CZMA issues.  First, on July 24, 2012, Entergy filed a supplement to the Indian Point license renewal application currently pending before the NRC.  The supplement states that, based on applicable federal law and in light of prior reviews by the State of New York, the NRC may issue the requested renewed operating licenses for Indian Point without the need for an additional consistency review by the State of New York under the CZMA.  On July 30, 2012, Entergy filed a motion for declaratory order with the ASLB seeking confirmation of its position that no further CZMA consistency determination is required before the NRC may issue renewed licenses.  On April 5, 2013, the State of New York and Riverkeeper filed answers opposing Entergy’s motion.  The State of New York also filed a cross-motion for declaratory order seeking confirmation that Indian Point had not been previously reviewed, and that only the New York State Department of State (NYSDOS) could conduct a CZMA review for NRC license renewal purposes.  On April 15, 2013, the NRC Staff filed answers recommending the ASLB deny both Entergy’s and the State of New York’s motions for declaratory order.  On June 12, 2013, the ASLB denied Entergy’s and the State of New York’s motions, without prejudice, on the ground that consultation on the matter of previous review among the NRC, Entergy (as applicant), and the State of New York had not taken place, as the ASLB determined to be required.  There is no prescribed schedule or deadline for the consultation process.

Second, Entergy filed with the NYSDOS in November 2012 a petition for declaratory order that Indian Point is grandfathered under either of two criteria prescribed by the New York Coastal Management Program (NYCMP), which sets forth the state coastal policies applied in a CZMA consistency review.  NYSDOS denied the motion by order dated January 2013.  Entergy filed a petition for judicial review of NYSDOS’s decision with the New York State Supreme Court for Albany County in March 2013.  NYSDOS filed an opposition and oral argument was held in September 2013 on Entergy’s petition for judicial review.  It is uncertain when the court will act on the petition for review.  The losing party may file an appeal as of right with the next level state appellate court.

Third, on December 17, 2012, Entergy filed with NYSDOS a consistency determination explaining why Indian Point satisfies all applicable NYCMP policies.  Entergy included in the consistency determination a “reservation of rights” clarifying that Entergy does not concede NYSDOS’s right to conduct a new CZMA review for Indian Point.    The six-month federal deadline for state decision on a consistency determination runs from the date the submission is complete.  On January 16, 2013, NYSDOS notified Entergy that it deemed the consistency determination incomplete because it did not include the final version of a further supplement to the FSEIS that was targeted for subsequent issuance by NRC staff.  On June 28, 2013, NYSDOS notified Entergy that NYSDOS had received a copy of the final version of the FSEIS on June 20, 2013, and that NYSDOS’s review of the Indian Point consistency determination had begun on June 20, 2013.  In October 2013, Entergy and NYSDOS executed a stay agreement that extends the deadline for NYSDOS to decide Indian Point’s CZMA consistency certification to March 22, 2014.
 
 
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Management’s Financial Discussion and Analysis



ANO Damage and Outage

On March 31, 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator stator out of the turbine building.  The collapse resulted in the death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the ANO turbine building.  The turbine building serves both ANO 1 and 2 and is a non-radiological area of the plant.  ANO 2 reconnected to the grid on April 28, 2013 and ANO 1 reconnected to the grid on August 7, 2013.  The total cost of assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment is currently estimated to be approximately $100 million.  In addition, Entergy Arkansas incurred replacement power costs for ANO 2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage extended beyond the originally-planned duration of the refueling outage.  Each of the Utility operating companies has recovery mechanisms in place designed to recover its prudently-incurred fuel and purchased power costs.

Entergy Arkansas is assessing its options for recovering damages that resulted from the stator drop, including its insurance coverage and legal action.  Entergy is a member of Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage to the members’ nuclear generating plants, including ANO.  NEIL has notified Entergy that it believes that a $50 million course of construction sublimit applies to any loss associated with the lifting apparatus failure and stator drop at ANO.  Entergy has responded that it disagrees with NEIL's position and is evaluating its options for enforcing its rights under the policy.  On July 12, 2013, Entergy Arkansas filed a complaint in the Circuit Court in Pope County, Arkansas against the owner of the heavy-lifting apparatus that collapsed, an engineering firm, a general contractor, and certain individuals asserting claims of breach of contract, negligence, and gross negligence in connection with their responsibility for the stator drop.

In the second quarter 2013, Entergy Arkansas recorded an insurance receivable of $50 million based on the minimum amount that it expects to receive from NEIL.  This $50 million receivable offset approximately $35 million of capital spending, $13 million of operation and maintenance expense, and $2 million of incremental deferred refueling outage costs incurred for the recovery through September 30, 2013.  As of September 30, 2013, Entergy Arkansas has incurred approximately $33 million in capital spending, $11 million in operation and maintenance expense, and $1 million in incremental deferred refueling outage costs in excess of its recorded insurance receivable.

Human Capital Management Strategic Imperative

Entergy is engaged in a strategic imperative that is intended to optimize the organization through a process known as human capital management.  In July 2013 management completed a comprehensive review of Entergy’s organization design and processes.  This effort resulted in a new internal organization structure, which management expects to result in the elimination of approximately 800 employee positions.  Costs associated with this phase of human capital management, primarily implementation costs, severance expenses, and the effect on benefit plan expense, are expected to be in the range of $145 million to $185 million.  The majority of these costs are expected to be incurred by the end of 2013 and approximately $18 million has been incurred as of September 30, 2013.

Entergy Solutions District Energy Sales Agreement

Entergy Solutions District Energy, a business wholly-owned by Entergy in the Entergy Wholesale Commodities segment, owns and operates district energy assets serving the business districts in Houston and New Orleans.  In August 2013, Entergy signed agreements to sell Entergy Solutions District Energy for approximately $130 million, subject to adjustments.  Entergy Solutions District Energy’s book value as of September 30, 2013 was approximately $100 million.  The sale is expected to close in 2013.

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.


 
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Management’s Financial Discussion and Analysis


Capital Structure

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

   
September 30,
2013
 
December 31,
2012
         
Debt to capital
 
58.4% 
 
58.7% 
Effect of excluding the securitization bonds
 
(1.6%)
 
(1.8%)
Debt to capital, excluding securitization bonds (a)
 
56.8% 
 
56.9% 
Effect of subtracting cash
 
(0.8%)
 
(1.1%)
Net debt to net capital, excluding securitization bonds (a)
 
56.0% 
 
55.8% 

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

Net debt consists of debt less cash and cash equivalents.  Debt consists of notes payable and commercial paper, capital lease obligations, and long-term debt, including the currently maturing portion.  Capital consists of debt, common shareholders’ equity, and subsidiaries’ preferred stock without sinking fund.  Net capital consists of capital less cash and cash equivalents.  Entergy uses the 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.

Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in March 2018.  Entergy Corporation has the ability to issue letters of credit against 50% of the total borrowing capacity of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2013:


 
Capacity (a)
 
 
Borrowings
 
Letters
of Credit
 
Capacity
Available
(In Millions)
             
$3,500
 
$150
 
$8
 
$3,342

(a)
The capacity decreases to $3,490 million in March 2017.

A covenant in Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio of 65% or less of its total capitalization.  The calculation of this debt ratio under Entergy Corporation’s credit facility is different than the calculation of the debt to capital ratio above.  Entergy is currently in compliance with the covenant.  If Entergy fails to meet this ratio, or if Entergy or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility’s maturity date may occur.  See Note 4 to the financial statements for additional discussion of the Entergy Corporation credit facility and discussion of the Registrant Subsidiaries’ credit facilities.

See Note 4 to the financial statements herein for additional discussion of the Entergy Corporation commercial paper program.  In July 2013 the Board increased the commercial paper program limit to $1.5 billion.  As of September 30, 2013, Entergy Corporation had approximately $1,016 million of commercial paper outstanding.


 
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Management’s Financial Discussion and Analysis


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 2013 through 2015.  Following are updates to the discussion in the Form 10-K.

Capital Investment Plan Preliminary Estimate for 2014-2016

Entergy is developing its capital investment plan for 2014 through 2016 and currently anticipates that the Utility will make $5.8 billion in capital investments during that period and that Entergy Wholesale Commodities will make $1.0 billion in capital investments during that period.  In addition to routine capital spending to maintain operations, the Utility capital investment plan includes specific investments and initiatives such as the Ninemile Point Unit 6 self-build project; NRC post-Fukushima requirements for the Utility nuclear fleet; potential scrubbers at the White Bluff plant to meet pending Arkansas state requirements under the Clean Air Visibility Rule and compliance with the EPA’s Mercury and Air Toxic Standard rule;  and transmission spending to support economic development projects, reliability, and new compliance requirements.  The Entergy Wholesale Commodities capital investment plan includes significant projects required to continue the operation of the current generation fleet including component replacements, software, and security; NYPA value sharing; and dry cask storage, license renewal, and NRC post-Fukushima requirements for the Entergy Wholesale Commodities nuclear fleet.

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 Entergy’s earnings, financial strength, and future investment opportunities.  At its October 2013 meeting, the Board declared a dividend of $0.83 per share, which is the same quarterly dividend per share that Entergy has paid since the second quarter 2010.

Cash Flow Activity

As shown in Entergy’s Consolidated Statements of Cash Flows, cash flows for the nine months ended September 30, 2013 and 2012 were as follows:

   
2013
 
2012
   
(In Millions)
         
Cash and cash equivalents at beginning of period
 
$533 
 
$694 
         
Cash flow provided by (used in):
       
Operating activities
 
2,199 
 
2,220 
Investing activities
 
(2,058)
 
(2,323)
Financing activities
 
(309)
 
159 
Net increase (decrease) in cash and cash equivalents
 
(168)
 
56 
         
Cash and cash equivalents at end of period
 
$365 
 
$750 


 
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Management’s Financial Discussion and Analysis


Operating Activities

Net cash provided by operating activities decreased by approximately $21 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to:

·  
an increase of $65 million in income tax payments;
·  
an increase of $46 million in spending on nuclear refueling outages in 2013 as compared to the same period in prior year;
·  
approximately $27 million in spending related to the generator stator incident at ANO, as discussed previously;
·  
higher deferred fuel refunds in 2013 as compared to the same period in prior year; and
·  
an increase of approximately $12 million in storm restoration spending in 2013 resulting from the Arkansas December 2012 winter storm and Hurricane Isaac.

These decreases in cash flow were partially offset by:

·  
higher Utility net revenues in 2013 resulting from additional generation investments made in 2012;
·  
a decrease of $65 million in pension contributions, substantially offset by an increase of $50 million in lump sum retirement payments out of the non-qualified pension plan.  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;
·  
proceeds of $72 million received in 2013 from the U.S. Department of Energy resulting from litigation regarding the storage of spent nuclear fuel.  The litigation is discussed in more detail in Part II, Item 5, “Spent Nuclear Fuel” and
·  
a refund of $31 million, including interest, paid to AmerenUE in June 2012.  The FERC ordered Entergy Arkansas to refund to AmerenUE the rough production cost equalization payments previously collected.  See Note 2 to the financial statements in the Form 10-K for further discussion of the FERC order.

Investing Activities

Net cash used in investing activities decreased by $265 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to:

·  
the withdrawal of a total of $260 million from storm reserve escrow accounts in 2013, primarily by Entergy Gulf States Louisiana and Entergy Louisiana, after Hurricane Isaac.  See Note 2 to the financial statements herein and in the Form 10-K for a discussion of Hurricane Isaac;
·  
a decrease in construction expenditures, primarily in the Utility business, resulting from spending in 2012 on the uprate project at Grand Gulf, substantially offset by storm restoration spending in 2013 resulting from the Arkansas December 2012 winter storm and Hurricane Isaac, spending in 2013 on the Ninemile 6 self-build project, and spending in 2013 related to the generator stator incident at ANO, as discussed previously; and
·  
$72.2 million of System Energy first mortgage bond proceeds deposited with a trustee in September 2012 and used in October 2012 for the redemption of another series of first mortgage bonds.

The decrease was partially offset by:

·  
a change in collateral deposit activity, reflected in the “Increase in other investments” line on the Consolidated Statement of Cash Flows, as Entergy returned net deposits of $49 million in 2013 and received net deposits of $16 million in 2012.  Entergy Wholesale Commodities’s forward sales contracts are discussed in the “Market and Credit Risk Sensitive Instruments” section below; and
·  
proceeds of $21 million received in 2013 compared to proceeds of $109 million in 2012 from the U.S. Department of Energy resulting from litigation regarding the storage of spent nuclear fuel.  The litigation is discussed in more detail in Part II, Item 5, “Spent Nuclear Fuel.”
 
 
 
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Management’s Financial Discussion and Analysis


Financing Activities

Financing activities used $309 million in net cash for the nine months ended September 30, 2013 compared to providing $159 million in net cash for the nine months ended September 30, 2012 primarily due to:

·  
long-term debt activity using approximately $180 million of cash in 2013 compared to providing $260 million of cash in 2012.  Included in the long-term debt activity is $645 million in 2013 and $605 million in 2012 for the repayment of borrowings on the Entergy Corporation long-term credit facility.  Entergy Corporation issued $351 million of commercial paper in 2013 and $154 million in 2012, in part, to repay borrowings on its long-term credit facility;
·  
a net decrease of $72 million in short-term borrowings by the nuclear fuel company variable interest entities;
·  
$51 million in proceeds from the sale to a third party in 2012 of a portion of Entergy Gulf States Louisiana’s investment in Entergy Holdings Company’s Class A preferred membership interests; and
·  
the repayment of $50 million in borrowings on Entergy Louisiana’s credit facility in 2012.

For details of long-term debt activity and Entergy's commercial paper program in 2013 see Note 4 to the financial statements herein.

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 the Form 10-K for a discussion of federal regulatory proceedings.  Following are updates to that discussion.

System Agreement

Utility Operating Company Notices of Termination of System Agreement Participation

As discussed in the Form 10-K, in February 2009, Entergy Arkansas and Entergy Mississippi filed with the FERC their notices of cancellation to terminate their participation in the System Agreement, effective December 18, 2013 and November 7, 2015, respectively.  In November 2009 the FERC accepted the notices of cancellation and determined that Entergy Arkansas and Entergy Mississippi are permitted to withdraw from the System Agreement following the 96-month notice period without payment of a fee or the requirement to otherwise compensate the remaining Utility operating companies as a result of withdrawal.  In February 2011 the FERC denied the LPSC’s and the City Council’s rehearing requests.  In September and October 2012 the U.S. Court of Appeals for the D.C. Circuit denied the LPSC’s and the City Council’s appeals of the FERC decisions.  In January 2013 the LPSC and the City Council filed a petition for a writ of certiorari with the U.S. Supreme Court.  On May 13, 2013, the U.S. Supreme Court denied the petition for a writ of certiorari filed by the LPSC and the City Council seeking review of the D.C. Circuit’s decision to affirm the FERC’s orders accepting the notices of cancellation filed by Entergy Arkansas and Entergy Mississippi and determining that Entergy Arkansas and Entergy Mississippi are permitted to withdraw from the System Agreement following the 96-month notice period without payment of a fee or the requirement to otherwise compensate the remaining Utility operating companies as a result of withdrawal.
 
 
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Management’s Financial Discussion and Analysis

 
In November 2012 the Utility operating companies filed amendments to the System Agreement with the FERC pursuant to section 205 of the Federal Power Act.  The LPSC, MPSC, PUCT, and City Council filed protests at the FERC regarding the amendments and other aspects of the Utility operating companies’ future operating arrangements, including requests that the continued viability of the System Agreement in MISO (among other issues) be set for hearing by the FERC.  On March 12, 2013, the Utility operating companies filed an answer to the protests.  The answer proposed, among other things, that: (1) the FERC allow the System Agreement revisions to go into effect as of December 19, 2013, without a hearing and for an initial two-year transition period; (2) no later than October 18, 2013, Entergy Services submit a filing pursuant to section 205 of the Federal Power Act that provides Entergy Texas’s notice of cancellation to terminate participation in the System Agreement and responds to the PUCT’s position that Entergy Texas be allowed to terminate its participation prior to the end of the mandatory 96-month notice period; and (3) at least six months prior to the end of the two-year transition period, Entergy Services submits an additional filing under section 205 of the Federal Power Act that addresses the allocation of MISO charges and credits among the Utility operating companies that remain in the System Agreement.  The answer further provided that prior to the filing which was to be made no later than October 18, 2013, Entergy Services, Entergy Texas, and Entergy would exercise reasonable best efforts to engage the Utility operating companies and their retail regulators in searching for a consensual means of allowing Entergy Texas to exit the System Agreement prior to the end of the mandatory 96-month notice period.  The matter remains pending at the FERC.

On October 11, 2013 the Utility operating companies filed with the FERC to amend the System Agreement changing the notice period for an operating company to terminate its participation in the System Agreement from ninety-six months to sixty months.  The proposed amendment also clarifies that the revised notice period will apply to any written notice of termination provided by an operating company on or after October 12, 2013.  On October 18, 2013, Entergy Texas provided notice to terminate its participation in the System Agreement effective after expiration of the proposed 60-month notice period or such other period as approved by FERC.  The proposed amendment and Entergy Texas’s termination notice are without prejudice to continuing efforts among affected operating companies and their retail regulators to search for a consensual means of allowing Entergy Texas an early exit from the System Agreement, which could be different from that proposed in the October 11, 2013 FERC filing.  Comments on both filings are due in November 2013.

Entergy’s Proposal to Join MISO

See the Form 10-K for a discussion of the Utility operating companies’ proposal to join MISO.  Following are updates to that discussion.

On April 8, 2013, the APSC issued an order resolving the outstanding issues in Entergy Arkansas’s change of control docket and granted Entergy Arkansas’s application subject to the conditions set forth in the APSC’s October 2012 order.  On May 23, 2013, the FERC issued an order accepting the changes to Appendix K of the MISO Transmission Owners Agreement proposed by MISO and a majority of the MISO transmission owners to implement MISO governance enhancements consistent with the APSC’s October 2012 order.

Because Entergy Arkansas also owns limited transmission facilities in Missouri, on March 21, 2013, Entergy Arkansas responded to attempts by certain parties to raise issues before the Missouri Public Service Commission pertaining to Entergy Arkansas’s integration into MISO by filing a notice that it was joining MISO.  On October 9, 2013, the Missouri Public Service Commission issued an order approving Entergy Arkansas’s integration of its Missouri transmission assets into MISO, subject to conditions.  The order includes conditions, however, that are beyond Entergy Arkansas’s control to satisfy and that concern wholesale tariffs that fall within the exclusive jurisdiction of the FERC.  Among other things, the order requires Entergy Arkansas and ITC Midwest to hold harmless non-MISO Missouri retail customers from increased costs due to the integration of Entergy Arkansas’s Missouri transmission facilities into MISO.  Entergy Arkansas is evaluating the Missouri Public Service Commission’s order and determining
 
 
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Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis


appropriate next steps, including seeking rehearing of that order.  The order is limited, however, to the 87 miles of Entergy Arkansas transmission facilities located in Missouri that are used to provide only interstate transmission service in Missouri; Entergy Arkansas does not have any retail customers in Missouri.  Entergy Arkansas plans to proceed with integration of its non-Missouri assets into the MISO RTO on December 19, 2013, as approved by the APSC.  Assuming the Missouri Public Service Commission’s order remains in force in its current form, Entergy Arkansas will not transfer functional control of its Missouri transmission facilities to MISO on December 19, 2013.  In that event, transmission service over the Missouri transmission facilities will be provided for a period of time by Entergy Arkansas under a FERC-jurisdictional open access transmission tariff, not the MISO tariff.  Entergy Arkansas filed with FERC the open access transmission tariff for its Missouri transmission assets on October 15, 2013, and requested an effective date of December 19, 2013, the date of the Utility operating companies’ planned MISO integration.  On October 16, 2013, Entergy Arkansas and MISO jointly filed an agreement that provides for coordination between the Entergy Arkansas tariff and the MISO tariff with respect to transmission service request processing, transmission rates, congestion management, data submission, and other matters.

On January 23, 2013, Entergy Arkansas filed with the APSC a Motion to Discontinue Activities Necessary to Operate as a True Stand-Alone Electric Utility, with supporting testimony, in which Entergy Arkansas requested an order from the APSC authorizing it to drop the stand-alone option by March 1, 2013.  On April 8, 2013, the APSC issued an order granting Entergy Arkansas’s motion.

On September 18, 2013, the APSC issued an order directing Entergy Arkansas and MISO to appear and show cause why the APSC should not find that Entergy Arkansas and MISO are in violation of certain conditions in a previous order in the proceeding.  The APSC directed Entergy Arkansas to demonstrate its earlier commitment to comply with the conditions by affirming that Entergy Arkansas would comply with five directives enumerated in the show cause order relating to the manner in which Entergy Arkansas conducts transmission planning.  On October 8, 2013, Entergy Arkansas and MISO submitted testimony in compliance with the show cause order.  In its compliance testimony, Entergy Arkansas specifically affirmed its intent to comply with the five directives set forth in the show cause order and provided detail regarding the manner in which it would comply with those directives.

On April 3, 2013, the PUCT staff filed a study performed by its independent consultant assessing Entergy Texas’s January 2013 updated analysis of the effect of termination of certain purchased power agreements on Entergy Texas’s costs upon Entergy Texas’s exit from the System Agreement.  While the independent consultant study concluded that the adjustments made in Entergy Texas’s updated analysis were analytically correct, the consultant also recommended further study regarding the effect of the termination of the purchased power agreements on the benefits associated with Entergy Texas joining MISO.  On April 5, 2013, Entergy Texas filed a response to the consultant study, noting a number of errors in the analysis and recommending against any further study of this matter.  At the direction of the PUCT, Entergy Texas subsequently agreed to fund further analysis, to be performed by a different independent consultant for the PUCT, regarding the effects of termination of these purchased power agreements.  On August 6, 2013, the report of the PUCT’s second independent consultant regarding the effects of termination of these purchased power agreements was filed with the PUCT as part of a larger report addressing the results of the consultant’s comprehensive analysis of Entergy Texas’s transition to operations post-exit of the System Agreement.  The report concluded (consistent with Entergy Texas’s updated analysis) that under both the “Foundation Case” capacity price forecast and the high capacity price sensitivity that were performed, Entergy Texas and its customers would be better off on a present-value basis if these purchased power agreements terminate.  Under the low capacity price sensitivity, there was a net cost to Entergy Texas customers if these purchased power agreements terminate.  Consistent with the requirements of the PUCT conditional order approving the change in control to MISO, Entergy Texas gave notice of cancellation to terminate its participation in the System Agreement on October 18, 2013.

In April 2012 the FERC conditionally accepted MISO’s proposal related to the allocation of transmission upgrade costs in connection with the transition and integration of the Utility operating companies into MISO.  In November 2012 the FERC issued an order denying the requests for rehearing of the April 2012 order, and conditionally accepting MISO’s May 2012 compliance filing, subject to a further compliance filing due within 30 days of the date of the November 2012 order.  In December 2012, MISO and the MISO Transmission Owners submitted to FERC a request for rehearing and proposed revisions to the MISO Tariff in compliance with FERC’s November 2012 order.   On July 11, 2013, the FERC issued an order conditionally accepting MISO’s compliance filing and granting in part and denying in part the request for rehearing.
 
 
22

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis



On February 15, 2013, Entergy Services, on behalf of the Utility operating companies, made a filing with the FERC requesting to adopt the standard Attachment O formula rate template used by transmission owners to establish transmission rates within MISO.  The filing proposed four transmission pricing zones for the Utility operating companies, one for Entergy Arkansas, one for Entergy Mississippi, one for Entergy Texas, and one for Entergy Louisiana, Entergy Gulf States Louisiana, and Entergy New Orleans.  On June 20, 2013, the FERC issued an order accepting the use of four transmission pricing zones, consolidated the proposed revisions to the Attachment O templates in this proceeding with certain other proceedings related to the ITC transaction, and set for hearing and settlement judge procedures those issues of material fact that FERC decided could not be resolved based on the existing record.  Several parties, including the City Council, filed requests for rehearing of the June 2013 order.

Also on February 15, 2013, MISO and Entergy Arkansas and Entergy Mississippi filed with the FERC proposed revisions to Attachment P of the MISO Tariff, to list the existing transmission and related agreements between each of Entergy Arkansas and Entergy Mississippi and each of their counterparties as grandfathered agreements.  On May 31, 2013, the FERC issued an order accepting the proposed revisions, effective December 19, 2013, as requested.

In March 2013 the FERC issued an order conditionally accepting MISO’s proposed tariff changes related to the allocation of long-term transmission rights and auction revenue rights, subject to a further compliance filing.  The amendments are intended to address the anticipated integration of the Utility operating companies, as well as other load-serving entities and transmission-owning utilities, into the MISO RTO.  In April 2013, MISO made the required compliance filing.  The FERC issued a letter order in September 2013 accepting MISO’s compliance filing.

FERC Reliability Standards Investigation

On March 19, 2013, the FERC issued an order approving a settlement between Entergy Services and the FERC Enforcement Staff (the Staff) arising from the Staff’s November 20, 2012 “Notice of Alleged Violations” which stated that the Staff had concluded that Entergy Services’s practices in certain areas violated various requirements of the North American Electric Reliability Corporation reliability standards.  Under the terms of the settlement, Entergy Services neither admits nor denies the alleged violations, but agrees to pay a civil penalty of $975,000 and undertake certain mitigation activities agreed to during discussions with Staff.

Market and Credit Risk Sensitive Instruments

Commodity Price Risk

Power Generation

As a wholesale generator, Entergy Wholesale Commodities’s core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities enters into forward contracts with its customers and sells energy in the day ahead or spot markets.  In addition to selling the energy produced by its plants, Entergy Wholesale Commodities sells unforced capacity, which allows load-serving entities to meet specified reserve and related requirements placed on them by the ISOs in their respective areas.  Entergy Wholesale Commodities’s forward physical power contracts consist of contracts to sell energy only, contracts to sell capacity only, and bundled contracts in which it sells both capacity and energy.  While the terminology and payment mechanics vary in these contracts, each of these types of contracts requires Entergy Wholesale Commodities to deliver MWh of energy, make capacity available, or both.  In addition to its forward physical power contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, put and/or call options, to manage forward commodity price risk.  Certain hedge volumes have price downside and upside relative to market price movement.  The contracted minimum, expected value, and sensitivity are provided to show potential variations.  While the sensitivity reflects the minimum, it does not reflect the total maximum upside potential from higher market prices.  The information contained in the table below represents projections at a point in time and will vary over time based on numerous factors, such as future market prices, contracting activities, and generation.  Following is a summary of Entergy Wholesale Commodities’s current forward capacity and generation contracts as well as total revenue projections based on market prices as of September 30, 2013 (2013 represents the remainder of the year):
 
 
23

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis



Entergy Wholesale Commodities Nuclear Portfolio

   
2013
 
2014
 
2015
 
2016
 
2017
 
2018
                         
Energy
                       
Percent of planned generation under contract (a):
                       
Unit-contingent (b)
 
45%
 
21%
 
15%
 
16%
 
14%
 
14%
Unit-contingent with availability guarantees (c)
 
13%
 
16%
 
14%
 
14%
 
15%
 
3%
Firm LD (d)
 
24%
 
64%
 
23%
 
-%
 
-%
 
-%
Offsetting positions (e)
 
-%
 
(20)%
 
-%
 
-%
 
-%
 
-%
Total
 
82%
 
81%
 
52%
 
30%
 
29%
 
17%
Planned generation (TWh) (f) (g)
 
11
 
40
 
35
 
36
 
35
 
35
Average revenue per MWh on contracted volumes:
                       
Minimum
 
$43
 
$44
 
$44
 
$50
 
$51
 
$56
Expected based on market prices as of September 30, 2013
 
$44
 
$47
 
$48
 
$50
 
$52
 
$56
Sensitivity: -/+ $10 per MWh market price change
 
$43-$46
 
$44-$50
 
$44-$53
 
$50-$53
 
$51-$54
 
$56
                         
Capacity
                       
Percent of capacity sold forward (h):
                       
Bundled capacity and energy contracts (i)
 
16%
 
16%
 
18%
 
18%
 
18%
 
18%
Capacity contracts (j)
 
53%
 
19%
 
15%
 
15%
 
6%
 
-%
Total
 
69%
 
35%
 
33%
 
33%
 
24%
 
18%
Planned net MW in operation (g)
 
5,011
 
5,011
 
4,406
 
4,406
 
4,406
 
4,406
Average revenue under contract per kW per month
(applies to capacity contracts only)
 
$3.0
 
$2.4
 
$3.2
 
$3.4
 
$3.6
 
$-
                         
Total Nuclear Energy and Capacity Revenues (m)
                       
Expected sold and market total revenue per MWh
 
$47
 
$51
 
$50
 
$50
 
$50
 
$51
Sensitivity: -/+ $10 per MWh market price change
 
$44-$51
 
$47-$55
 
$44-$57
 
$43-$57
 
$43-$57
 
$44-$59


 
24

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis


Entergy Wholesale Commodities Non-Nuclear Portfolio

   
2013
 
2014
 
2015
 
2016
 
2017
 
2018
                         
Energy
                       
Percent of planned generation under contract (a):
                       
Cost-based contracts (k)
 
33%
 
34%
 
35%
 
34%
 
32%
 
33%
Firm LD (d)
 
5%
 
6%
 
7%
 
6%
 
6%
 
7%
Total
 
38%
 
40%
 
42%
 
40%
 
38%
 
40%
Planned generation (TWh) (f) (l)
 
2
 
6
 
6
 
6
 
6
 
6
                         
Capacity
                       
Percent of capacity sold forward (h):
                       
Cost-based contracts (k)
 
24%
 
24%
 
24%
 
24%
 
26%
 
26%
Bundled capacity and energy contracts (i)
 
8%
 
8%
 
8%
 
8%
 
8%
 
8%
Capacity contracts (j) (n)
 
53%
 
53%
 
53%
 
53%
 
23%
 
-%
Total
 
85%
 
85%
 
85%
 
85%
 
57%
 
34%
Planned net MW in operation (l)
 
1,052
 
1,052
 
1,052
 
1,052
 
977
 
977

(a)
Percent of planned generation output sold or purchased forward under contracts, forward physical contracts, forward financial contracts, or options that mitigate price uncertainty that may require regulatory approval or approval of transmission rights.
(b)
Transaction under which power is supplied from a specific generation asset; if the asset is not operating, seller is generally not liable to buyer for any damages.
(c)
A sale of power on a unit-contingent basis coupled with a guarantee of availability provides for the payment to the power purchaser of contract damages, if incurred, in the event the seller fails to deliver power as a result of the failure of the specified generation unit to generate power at or above a specified availability threshold.  All of Entergy’s outstanding guarantees of availability provide for dollar limits on Entergy’s maximum liability under such guarantees.
(d)
Transaction that requires receipt or delivery of energy at a specified delivery point (usually at a market hub not associated with a specific asset) or settles financially on notional quantities; if a party fails to deliver or receive energy, defaulting party must compensate the other party as specified in the contract, a portion of which may be capped through the use of risk management products.
(e)
Transactions for the purchase of energy, generally to offset a firm LD transaction.
(f)
Amount of output expected to be generated by Entergy Wholesale Commodities resources considering plant operating characteristics, outage schedules, and expected market conditions that affect dispatch.
(g)
Assumes NRC license renewals for plants whose current licenses expire within five years.  Assumes shutdown of Vermont Yankee in the fourth quarter 2014 and uninterrupted normal operation at remaining plants.  NRC license renewal applications are in process for two units, as follows (with current license expirations in parentheses): Indian Point 2 (September 2013 and now operating under its period of extended operations) and Indian Point 3 (December 2015).  For a discussion regarding the shutdown of the Vermont Yankee plant, see “Impairment of Long-Lived Assets” in Note 11 to the financial statements herein.  For a discussion regarding the license renewals for Indian Point 2 and Indian Point 3, see “Entergy Wholesale Commodities Authorizations to Operate Its Nuclear Power Plants” above.
(h)
Percent of planned qualified capacity sold to mitigate price uncertainty under physical or financial transactions.
(i)
A contract for the sale of installed capacity and related energy, priced per megawatt-hour sold.
(j)
A contract for the sale of an installed capacity product in a regional market.
(k)
Contracts priced in accordance with cost-based rates, a ratemaking concept used for the design and development of rate schedules to ensure that the filed rate schedules recover only the cost of providing the service; these contracts are on owned non-utility resources located within Entergy’s Utility service area, which do not operate under market-based rate authority.  The percentage sold assumes approval of long-term transmission rights.
 
 
 
25

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis


(l)
Non-nuclear planned generation and net MW in operation include purchases from affiliated and non-affiliated counterparties under long-term contracts and exclude energy and capacity from Entergy Wholesale Commodities’s wind investment and from the 544 MW Ritchie plant that is not planned to operate.
(m)
Includes expectations for the new New York ISO Lower Hudson Valley capacity zone starting in May 2014.
(n)
The increase from the amount reported in the Form 10-K in capacity contracts sold in 2016 and 2017 is due to prorated MWs from Rhode Island State Energy Center offsetting Vermont Yankee commitments in ISO New England forward capacity auction #7.

Entergy estimates that a positive $10 per MWh change in the annual average energy price in the markets in which the Entergy Wholesale Commodities nuclear business sells power, based on September 30, 2013 market conditions, planned generation volumes, and hedged positions, would have a corresponding effect on pre-tax net income of $43 million for the remainder of 2013. A negative $10 per MWh change in the annual average energy price in the markets based on September 30, 2013 market conditions would have a corresponding effect on pre-tax net income of ($26) million for the remainder of 2013.

Some of the agreements to sell the power produced by Entergy Wholesale Commodities’s power plants contain provisions that require an Entergy subsidiary to provide collateral to secure its obligations under the agreements.  The Entergy subsidiary is required to provide collateral based upon the difference between the current market and contracted power prices in the regions where Entergy Wholesale Commodities sells power.  The primary form of collateral to satisfy these requirements is an Entergy Corporation guaranty.  Cash and letters of credit are also acceptable forms of collateral.  At September 30, 2013, based on power prices at that time, Entergy had liquidity exposure of $200 million under the guarantees in place supporting Entergy Wholesale Commodities transactions, $20 million of guarantees that support letters of credit, and $9 million of posted cash collateral.  As of September 30, 2013, the liquidity exposure associated with Entergy Wholesale Commodities assurance requirements, including return of previously posted collateral from counterparties, would increase by $110 million for a $1 per MMBtu increase in gas prices in both the short-and long-term markets.  In the event of a decrease in Entergy Corporation’s credit rating to below investment grade, based on power prices as of September 30, 2013, Entergy would have been required to provide approximately $79 million of additional cash or letters of credit under some of the agreements.

As of September 30, 2013, substantially all of the counterparties or their guarantors for 100% of the planned energy output under contract for Entergy Wholesale Commodities nuclear plants through 2017 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.

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, unbilled revenue, impairment of long-lived assets and trust fund investments, qualified pension and other postretirement benefits, and other contingencies.  Following is an update to that discussion.

Nuclear Decommissioning Costs

In the first quarter 2013, Entergy Wholesale Commodities recorded a revision to its estimated decommissioning cost liability for a nuclear site as a result of a revised decommissioning cost study.  The revised estimate resulted in a $46.6 million reduction in the decommissioning cost liability, along with a corresponding reduction in the related asset retirement cost asset.


 
26

Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis


In the third quarter 2013, Entergy Wholesale Commodities recorded a revision to its estimated decommissioning cost liability for Vermont Yankee as a result of a revised decommissioning cost study. The revised estimate resulted in a $58 million increase in the decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset. The increase in the estimated decommissioning cost liability resulted from the change in expectation regarding the timing of decommissioning cash flows due to the decision to cease operations of the plant.  See Note 11 to the financial statements herein for further discussion of the Vermont Yankee plant.

Assuming the end of Vermont Yankee operations in the fourth quarter 2014, the amount required to meet the NRC minimum for decommissioning financial assurance for license termination is $566 million. The Vermont Yankee decommissioning trust had a balance of approximately $584 million as of September 30, 2013, excluding the $40 million guarantee by Entergy Corporation to satisfy NRC requirements following the 2009 review of financial assurance levels. Filings with the NRC for planned shutdown activities will determine whether any other financial assurance may be required and will specifically address funding for spent fuel management, which will be required until the federal government takes possession of the fuel and removes it from the site, per its current obligations.

New Accounting Pronouncements

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



CONSOLIDATED STATEMENTS OF INCOME
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
   
Three Months Ended
   
Nine Months Ended
 
   
2013
   
2012
   
2013
   
2012
 
      (In Thousands, Except Share Data)  
                         
OPERATING REVENUES
                       
Electric
  $ 2,704,800     $ 2,320,360     $ 6,831,290     $ 6,039,752  
Natural gas
    26,113       23,557       113,315       93,444  
Competitive businesses
    621,046       619,643       1,754,436       1,732,624  
TOTAL
    3,351,959       2,963,560       8,699,041       7,865,820  
                                 
OPERATING EXPENSES
                               
Operating and Maintenance:
                               
   Fuel, fuel-related expenses, and
                               
     gas purchased for resale
    818,254       596,270       1,818,194       1,572,265  
   Purchased power
    392,545       336,552       1,251,418       966,816  
   Nuclear refueling outage expenses
    64,758       62,582       191,940       184,288  
   Asset impairment and related charges
    291,505       -       291,505       355,524  
   Other operation and maintenance
    839,348       765,242       2,437,801       2,259,758  
Decommissioning
    60,848       56,796       179,342       126,641  
Taxes other than income taxes
    156,950       149,049       452,934       424,329  
Depreciation and amortization
    325,149       281,740       923,541       836,711  
Other regulatory charges
    13,708       24,477       22,914       162,509  
TOTAL
    2,963,065       2,272,708       7,569,589       6,888,841  
                                 
OPERATING INCOME
    388,894       690,852       1,129,452       976,979  
                                 
OTHER INCOME
                               
Allowance for equity funds used during construction
    17,676       18,396       46,675       70,986  
Interest and investment income
    23,430       24,490       102,277       94,767  
Miscellaneous - net
    (10,214 )     (10,768 )     (36,992 )     (41,794 )
TOTAL
    30,892       32,118       111,960       123,959  
                                 
INTEREST EXPENSE
                               
Interest expense
    157,504       155,800       466,422       452,162  
Allowance for borrowed funds used during construction
    (6,453 )     (8,003 )     (18,432 )     (27,877 )
TOTAL
    151,051       147,797       447,990       424,285  
                                 
INCOME BEFORE INCOME TAXES
    268,735       575,173       793,422       676,653  
                                 
Income taxes
    24,553       232,503       214,202       110,140  
                                 
CONSOLIDATED NET INCOME
    244,182       342,670       579,220       566,513  
                                 
Preferred dividend requirements of subsidiaries
    4,332       5,582       14,247       16,108  
                                 
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION
  $ 239,850     $ 337,088     $ 564,973     $ 550,405  
                                 
                                 
Earnings per average common share:
                               
    Basic
  $ 1.35     $ 1.90     $ 3.17     $ 3.11  
    Diluted
  $ 1.34     $ 1.89     $ 3.16     $ 3.10  
Dividends declared per common share
  $ 0.83     $ 0.83     $ 2.49     $ 2.49  
                                 
Basic average number of common shares outstanding
    178,283,721       177,517,846       178,170,339       177,184,464  
Diluted average number of common shares outstanding
    178,652,210       177,975,075       178,520,063       177,636,549  
                                 
See Notes to Financial Statements.
                               



CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
   
Three Months Ended
   
Nine Months Ended
 
   
2013
   
2012
   
2013
   
2012
 
      (In Thousands)  
                         
Net Income
  $ 244,182     $ 342,670     $ 579,220     $ 566,513  
                                 
Other comprehensive income (loss)
                               
   Cash flow hedges net unrealized losses
                               
     (net of tax benefit of ($17,199), ($57,231), ($43,803), and ($40,012))
    (31,663 )     (106,138 )     (80,048 )     (68,793 )
   Pension and other postretirement liabilities
                               
     (net of tax expense of $10,301, $3,643, $22,055, and $17,998)
    15,430       6,197       35,004       29,524  
   Net unrealized investment gains
                               
     (net of tax expense of $20,819, $29,657, $65,805, and $67,046)
    46,300       38,430       94,644       70,512  
   Foreign currency translation
                               
     (net of tax expense (benefit) of $380, $170, ($25), and $224)
    706       315       (47 )     416  
         Other comprehensive income (loss)
    30,773       (61,196 )     49,553       31,659  
                                 
Comprehensive Income
    274,955       281,474       628,773       598,172  
                                 
Preferred dividend requirements of subsidiaries
    4,332       5,582       14,247       16,108  
                                 
Comprehensive Income Attributable to Entergy Corporation
  $ 270,623     $ 275,892     $ 614,526     $ 582,064  
                                 
                                 
See Notes to Financial Statements.
                               
 

CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2013 and 2012
(Unaudited)
   
2013
   
2012
 
   
(In Thousands)
 
             
OPERATING ACTIVITIES
           
Consolidated net income
  $ 579,220     $ 566,513  
Adjustments to reconcile consolidated net income to net cash flow
               
 provided by operating activities:
               
  Depreciation, amortization, and decommissioning, including nuclear fuel amortization
    1,472,985       1,293,667  
  Deferred income taxes, investment tax credits, and non-current taxes accrued
    174,052       111,228  
  Asset impairment and related charges
    291,505       355,524  
  Changes in working capital:
               
     Receivables
    (273,876 )     (162,015 )
     Fuel inventory
    16,421       (9,063 )
     Accounts payable
    (80,626 )     143,596  
     Prepaid taxes and taxes accrued
    (6,150 )     44,625  
     Interest accrued
    (25,586 )     (24,752 )
     Deferred fuel costs
    (43,419 )     (40,192 )
     Other working capital accounts
    (81,315 )     (131,374 )
  Changes in provisions for estimated losses
    (247,560 )     (17,479 )
  Changes in other regulatory assets
    173,164       49,250  
  Changes in other regulatory liabilities
    290,965       237,627  
  Changes in pensions and other postretirement liabilities
    (48,814 )     (75,104 )
  Other
    8,493       (122,263 )
Net cash flow provided by operating activities
    2,199,459       2,219,788  
                 
  INVESTING ACTIVITIES
               
Construction/capital expenditures
    (1,781,208 )     (1,868,690 )
Allowance for equity funds used during construction
    49,411       73,497  
Nuclear fuel purchases
    (398,456 )     (412,912 )
Payment for purchase of plant
    -       (645 )
Changes in securitization account
    (3,702 )     (2,036 )
NYPA value sharing payment
    (71,736 )     (72,000 )
Payments to storm reserve escrow account
    (5,882 )     (7,009 )
Receipts from storm reserve escrow account
    260,279       17,884  
Increase in other investments
    (43,656 )     (69,995 )
Litigation proceeds for reimbursement of spent nuclear fuel storage costs
    21,034       109,105  
Proceeds from nuclear decommissioning trust fund sales
    1,063,711       1,416,697  
Investment in nuclear decommissioning trust funds
    (1,147,571 )     (1,507,123 )
Net cash flow used in investing activities
    (2,057,776 )     (2,323,227 )
                 
See Notes to Financial Statements.
               
                 
 
 
ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2013 and 2012
(Unaudited)
      2013       2012  
   
(In Thousands)
 
                 
FINANCING ACTIVITIES
               
Proceeds from the issuance of:
               
  Long-term debt
    2,925,997       2,289,494  
  Mandatorily redeemable preferred membership units of subsidiary
    -       51,000  
  Treasury stock
    20,720       56,602  
Retirement of long-term debt
    (3,106,226 )     (2,029,016 )
Changes in credit borrowings and commercial paper - net
    310,042       247,845  
Dividends paid:
               
  Common stock
    (445,031 )     (441,292 )
  Preferred stock
    (14,469 )     (15,497 )
Net cash flow provided by (used in) financing activities
    (308,967 )     159,136  
                 
Effect of exchange rates on cash and cash equivalents
    47       (416 )
                 
Net increase (decrease) in cash and cash equivalents
    (167,237 )     55,281  
                 
Cash and cash equivalents at beginning of period
    532,569       694,438  
                 
Cash and cash equivalents at end of period
  $ 365,332     $ 749,719  
                 
                 
                 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
               
  Cash paid during the period for:
               
    Interest - net of amount capitalized
  $ 435,161     $ 422,142  
    Income taxes
  $ 107,560     $ 42,472  
                 
                 
See Notes to Financial Statements.
               
                 
 

CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2013 and December 31, 2012
(Unaudited)
             
   
2013
   
2012
 
   
(In Thousands)
 
             
CURRENT ASSETS
           
Cash and cash equivalents:
           
  Cash
  $ 102,949     $ 112,992  
  Temporary cash investments
    262,383       419,577  
     Total cash and cash equivalents
    365,332       532,569  
Securitization recovery trust account
    49,741       46,040  
Accounts receivable:
               
  Customer
    753,033       568,871  
  Allowance for doubtful accounts
    (33,482 )     (31,956 )
  Other
    170,620       161,408  
  Accrued unbilled revenues
    377,588       303,392  
     Total accounts receivable
    1,267,759       1,001,715  
Deferred fuel costs
    119,338       150,363  
Accumulated deferred income taxes
    84,059       306,902  
Fuel inventory - at average cost
    197,409       213,831  
Materials and supplies - at average cost
    906,119       928,530  
Deferred nuclear refueling outage costs
    245,992       243,374  
System agreement cost equalization
    6,256       16,880  
Prepayments and other
    247,585       242,922  
TOTAL
    3,489,590       3,683,126  
                 
OTHER PROPERTY AND INVESTMENTS
               
Investment in affiliates - at equity
    44,418       46,738  
Decommissioning trust funds
    4,627,774       4,190,108  
Non-utility property - at cost (less accumulated depreciation)
    260,076       256,039  
Other
    185,959       436,234  
TOTAL
    5,118,227       4,929,119  
                 
PROPERTY, PLANT AND EQUIPMENT
               
Electric
    42,662,320       41,944,567  
Property under capital lease
    933,058       935,199  
Natural gas
    361,441       353,492  
Construction work in progress
    1,599,127       1,365,699  
Nuclear fuel
    1,560,176       1,598,430  
TOTAL PROPERTY, PLANT AND EQUIPMENT
    47,116,122       46,197,387  
Less - accumulated depreciation and amortization
    19,548,683       18,898,842  
PROPERTY, PLANT AND EQUIPMENT - NET
    27,567,439       27,298,545  
                 
DEFERRED DEBITS AND OTHER ASSETS
               
Regulatory assets:
               
  Regulatory asset for income taxes - net
    860,169       742,030  
  Other regulatory assets (includes securitization property of
               
     $844,601 as of September 30, 2013 and $914,751 as of
               
     December 31, 2012)
    4,750,482       5,025,912  
  Deferred fuel costs
    172,202       172,202  
Goodwill
    377,172       377,172  
Accumulated deferred income taxes
    66,349       37,748  
Other
    922,496       936,648  
TOTAL
    7,148,870       7,291,712  
                 
TOTAL ASSETS
  $ 43,324,126     $ 43,202,502  
                 
See Notes to Financial Statements.
               
 
 
ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2013 and December 31, 2012
(Unaudited)
                 
      2013       2012  
   
(In Thousands)
 
                 
CURRENT LIABILITIES
               
Currently maturing long-term debt
  $ 206,260     $ 718,516  
Notes payable and commercial paper
    1,106,039       796,002  
Accounts payable
    900,131       1,217,180  
Customer deposits
    366,151       359,078  
Taxes accrued
    327,569       333,719  
Accumulated deferred income taxes
    35,095       13,109  
Interest accrued
    159,078       184,664  
Deferred fuel costs
    21,995       96,439  
Obligations under capital leases
    2,717       3,880  
Pension and other postretirement liabilities
    53,822       95,900  
System agreement cost equalization
    6,256       25,848  
Other
    253,915       261,986  
TOTAL
    3,439,028       4,106,321  
                 
NON-CURRENT LIABILITIES
               
Accumulated deferred income taxes and taxes accrued
    8,330,667       8,311,756  
Accumulated deferred investment tax credits
    266,547       273,696  
Obligations under capital leases
    32,814       34,541  
Other regulatory liabilities
    1,189,579       898,614  
Decommissioning and asset retirement cost liabilities
    3,702,881       3,513,634  
Accumulated provisions
    115,507       362,226  
Pension and other postretirement liabilities
    3,719,150       3,725,886  
Long-term debt (includes securitization bonds of $910,026 as of
               
  September 30, 2013 and $973,480 as of December 31, 2012)
    12,275,492       11,920,318  
Other
    563,499       577,910  
TOTAL
    30,196,136       29,618,581  
                 
Commitments and Contingencies
               
                 
Subsidiaries' preferred stock without sinking fund
    186,511       186,511  
                 
EQUITY
               
Common Shareholders' Equity:
               
Common stock, $.01 par value, authorized 500,000,000 shares;
               
  issued 254,752,788 shares in 2013 and in 2012
    2,548       2,548  
Paid-in capital
    5,362,424       5,357,852  
Retained earnings
    9,825,653       9,704,591  
Accumulated other comprehensive loss
    (243,530 )     (293,083 )
Less - treasury stock, at cost (76,446,813 shares in 2013 and
               
  76,945,239 shares in 2012)
    5,538,644       5,574,819  
Total common shareholders' equity
    9,408,451       9,197,089  
Subsidiaries' preferred stock without sinking fund
    94,000       94,000  
TOTAL
    9,502,451       9,291,089  
                 
TOTAL LIABILITIES AND EQUITY
  $ 43,324,126     $ 43,202,502  
                 
See Notes to Financial Statements.
               
                 


CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                                           
         
Common Shareholders' Equity
       
   
Subsidiaries' Preferred Stock
   
Common
Stock
   
Treasury
Stock
   
Paid-in
Capital
   
Retained Earnings
   
Accumulated Other Comprehensive Income (Loss)
   
Total
 
   
(In Thousands)
 
                                           
Balance at December 31, 2011
  $ 94,000     $ 2,548     $ (5,680,468 )   $ 5,360,682     $ 9,446,960     $ (168,452 )   $ 9,055,270  
                                                         
Consolidated net income (a)
    16,108       -       -       -       550,405       -       566,513  
Other comprehensive income
    -       -       -       -       -       31,659       31,659  
Common stock issuances related to stock plans
    -       -       95,857       (7,163 )     -       -       88,694  
Common stock dividends declared
    -       -       -       -       (441,506 )     -       (441,506 )
Preferred dividend requirements of subsidiaries (a)
    (16,108 )     -       -       -       -       -       (16,108 )
                                                         
Balance at September 30, 2012
  $ 94,000     $ 2,548     $ (5,584,611 )   $ 5,353,519     $ 9,555,859     $ (136,793 )   $ 9,284,522  
                                                         
                                                         
                                                         
Balance at December 31, 2012
  $ 94,000     $ 2,548     $ (5,574,819 )   $ 5,357,852     $ 9,704,591     $ (293,083 )   $ 9,291,089  
                                                         
Consolidated net income (a)
    14,247       -       -       -       564,973       -       579,220  
Other comprehensive income
    -       -       -       -       -       49,553       49,553  
Common stock issuances related to stock plans
    -       -       36,175       4,572       -       -       40,747  
Common stock dividends declared
    -       -       -       -       (443,911 )     -       (443,911 )
Preferred dividend requirements of subsidiaries (a)
    (14,247 )     -       -       -       -       -       (14,247 )
                                                         
Balance at September 30, 2013
  $ 94,000     $ 2,548     $ (5,538,644 )   $ 5,362,424     $ 9,825,653     $ (243,530 )   $ 9,502,451  
                                                         
See Notes to Financial Statements.
                                                       
                                                         
(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2013 and 2012 include $9.3 million and $11.1 million, respectively, of preferred dividends on subsidiaries' preferred stock without sinking fund that is not presented within equity.
 

 
 
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
                         
   
Three Months Ended
   
Increase/
       
Description
 
2013
   
2012
   
(Decrease)
   
%
 
   
(Dollars in Millions)
       
Utility Electric Operating Revenues:
                       
  Residential
  $ 1,140     $ 1,019     $ 121       12  
  Commercial
    720       627       93       15  
  Industrial
    673       536       137       26  
  Governmental
    60       54       6       11  
    Total retail
    2,593       2,236       357       16  
  Sales for resale
    46       45       1       2  
  Other
    66       39       27       69  
    Total
  $ 2,705     $ 2,320     $ 385       17  
                                 
Utility Billed Electric Energy
                               
 Sales (GWh):
                               
  Residential
    11,359       11,605       (246 )     (2 )
  Commercial
    8,393       8,433       (40 )     -  
  Industrial
    11,038       10,748       290       3  
  Governmental
    648       668       (20 )     (3 )
    Total retail
    31,438       31,454       (16 )     -  
  Sales for resale
    667       834       (167 )     (20 )
    Total
    32,105       32,288       (183 )     (1 )
                                 
                                 
Entergy Wholesale Commodities:
                               
Operating Revenues
  $ 623     $ 627     $ (4 )     (1 )
Billed Electric Energy Sales (GWh)
    11,630       12,002       (372 )     (3 )
                                 
                                 
   
Nine Months Ended
   
Increase/
         
Description
    2013       2012    
(Decrease)
   
%
 
   
(Dollars in Millions)
         
Utility Electric Operating Revenues:
                               
  Residential
  $ 2,620     $ 2,366     $ 254       11  
  Commercial
    1,817       1,653       164       10  
  Industrial
    1,815       1,531       284       19  
  Governmental
    165       149       16       11  
    Total retail
    6,417       5,699       718       13  
  Sales for resale
    145       105       40       38  
  Other
    269       236       33       14  
    Total
  $ 6,831     $ 6,040     $ 791       13  
                                 
Utility Billed Electric Energy
                               
 Sales (GWh):
                               
  Residential
    27,080       27,305       (225 )     (1 )
  Commercial
    21,498       21,994       (496 )     (2 )
  Industrial
    31,264       31,114       150       -  
  Governmental
    1,814       1,852       (38 )     (2 )
    Total retail
    81,656       82,265       (609 )     (1 )
  Sales for resale
    1,887       2,402       (515 )     (21 )
    Total
    83,543       84,667       (1,124 )     (1 )
                                 
                                 
Entergy Wholesale Commodities:
                               
Operating Revenues
  $ 1,771     $ 1,755     $ 16       1  
Billed Electric Energy Sales (GWh)
    33,189       34,957       (1,768 )     (5 )
                                 
 
 
 

ENTERGY CORPORATION AND SUBSIDIARIES

NOTES TO FINANCIAL STATEMENTS
(Unaudited)

NOTE 1.  COMMITMENTS AND CONTINGENCIES  (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business.  While management is unable to predict the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material 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, discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein, and discusses proceedings involving Vermont Yankee in Note 1 to the financial statements in the Form 10-K and in Note 11 to the financial statements herein.

ANO Damage and Outage

On March 31, 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator stator out of the turbine building.  The collapse resulted in the death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the ANO turbine building.  The turbine building serves both ANO 1 and 2 and is a non-radiological area of the plant.  ANO 2 reconnected to the grid on April 28, 2013 and ANO 1 reconnected to the grid on August 7, 2013.  The total cost of assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment is currently estimated to be approximately $100 million.  In addition, Entergy Arkansas incurred replacement power costs for ANO 2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage extended beyond the originally-planned duration of the refueling outage.  Each of the Utility operating companies has recovery mechanisms in place designed to recover its prudently-incurred fuel and purchased power costs.

Entergy Arkansas is assessing its options for recovering damages that resulted from the stator drop, including its insurance coverage and legal action.  Entergy is a member of Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage to the members’ nuclear generating plants, including ANO.  NEIL has notified Entergy that it believes that a $50 million course of construction sublimit applies to any loss associated with the lifting apparatus failure and stator drop at ANO.  Entergy has responded that it disagrees with NEIL's position and is evaluating its options for enforcing its rights under the policy.  On July 12, 2013, Entergy Arkansas filed a complaint in the Circuit Court in Pope County, Arkansas against the owner of the heavy-lifting apparatus that collapsed, an engineering firm, a general contractor, and certain individuals asserting claims of breach of contract, negligence, and gross negligence in connection with their responsibility for the stator drop.

In the second quarter 2013, Entergy Arkansas recorded an insurance receivable of $50 million based on the minimum amount that it expects to receive from NEIL.  This $50 million receivable offset approximately $35 million of capital spending, $13 million of operation and maintenance expense, and $2 million of incremental deferred refueling outage costs incurred for the recovery through September 30, 2013.  As of September 30, 2013, Entergy Arkansas has incurred approximately $33 million in capital spending, $11 million in operation and maintenance expense, and $1 million in incremental deferred refueling outage costs in excess of its recorded insurance receivable.


 
36

Entergy Corporation and Subsidiaries
Notes to Financial Statements


Baxter Wilson Plant Event

On September 11, 2013, Entergy Mississippi’s Baxter Wilson (Unit 1) power plant experienced a significant unplanned outage event.  The cause of the event is currently under investigation.  Entergy Mississippi is still in the process of assessing the nature and extent of the damage to the unit. The current estimate of costs to return the unit to service, however, is in the range of $25 million to $30 million.  This estimate and return to service schedule may change as restorative activities occur.  The costs necessary to return the plant to service are expected to be incurred during the fourth quarter 2013 through the second quarter 2014.  Entergy Mississippi believes that the damage is covered by its property insurance policy, subject to a $20 million deductible.

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.

Conventional Property Insurance

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

Employment Litigation

The Registrant Subsidiaries and other Entergy subsidiaries are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees and third parties not selected for open positions.  These actions include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board; claims of retaliation; and claims for or regarding benefits under various Entergy Corporation sponsored plans.  Entergy and the Registrant Subsidiaries are responding to these lawsuits and proceedings and deny liability to the claimants.

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

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation at Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas.


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

Regulatory Assets

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that information.
 
 
37

Entergy Corporation and Subsidiaries
Notes to Financial Statements



Fuel and Purchased Power Cost Recovery

Entergy Louisiana

In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings.  The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009.  The LPSC Staff issued its audit report in January 2013.  The LPSC staff recommended that Entergy Louisiana refund approximately $1.9 million, plus interest, to customers and realign the recovery of approximately $1 million from Entergy Louisiana’s fuel adjustment clause to base rates.  The recommended refund was made by Entergy Louisiana in May 2013 in the form of a credit to customers through its fuel adjustment clause filing.  Two parties have intervened in the proceeding.  A procedural schedule has been established for the identification of issues by the intervenors and for Entergy Louisiana to submit comments regarding the LPSC Staff report and any issues raised by intervenors.  One intervenor is seeking further proceedings regarding certain issues it raised in its comments on the LPSC Staff report.  Entergy Louisiana has filed responses to both the LPSC Staff report and the issues raised by the intervenor.  As required by the procedural schedule, a joint status report was submitted in October 2013 by the parties.  That report requests that a status conference be convened by the ALJ to address open issues, including whether further proceedings will be required.  A status conference has been scheduled for December 5, 2013.

Entergy Texas

In November 2012, Entergy Texas filed a pleading seeking a PUCT finding that special circumstances exist for limited cost recovery of capacity costs associated with two purchased power agreements until such time that these costs are included in base rates or a purchased capacity recovery rider or other recovery mechanism.  In March 2013 the PUCT Staff and intervenors filed a joint motion to dismiss Entergy Texas’s application seeking special circumstances recovery of these capacity costs.  Entergy Texas filed to withdraw this case without prejudice and the judge granted the request in June 2013.

At the April 11, 2013 open meeting, the PUCT Commissioners discussed their view that a purchased power capacity rider was good public policy.   The PUCT issued an order on May 28, 2013 adopting the rule allowing for a purchased power capacity rider, subject to an offsetting adjustment for load growth.  The rule, as adopted, also includes a process for obtaining pre-approval by the PUCT of purchased power agreements.  Entergy Texas has not exercised the option to recover its capacity costs under the new rider mechanism due to the pending base rate case filed with the PUCT in September 2013, but will continue to evaluate the benefits of utilizing the new rider to recover future capacity costs.

Retail Rate Proceedings

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

Filings with the APSC (Entergy Arkansas)

Retail Rates

2013 Base Rate Filing

In March 2013, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs.  Recognizing that the final structure of Entergy Arkansas’s transmission business has not been determined, the filing presents two alternative scenarios for the APSC to establish the appropriate level of rates for Entergy Arkansas.  In the primary scenario, which assumes that Entergy Arkansas will transition to MISO in December 2013, Entergy Arkansas requests a rate increase of $174 million, including $49 million of revenue being transferred from collection in riders to base rates.  The alternate scenario, which also assumes completion of the proposed spin-merge of the transmission business with ITC, reflects a $218 million total rate increase request.  Both scenarios propose a new transmission rider and a capacity cost recovery rider.  The filing requests a 10.4% return on common equity.  In September 2013 Entergy Arkansas filed testimony reflecting an updated rate increase request of $145 million in the primary scenario, with no change to its requested return on common equity of 10.4%.  Hearings in the proceeding began in October 2013, and an APSC decision is pending.  New rates are expected to become effective by January 2014.


 
38

Entergy Corporation and Subsidiaries
Notes to Financial Statements


Filings with the LPSC

Retail Rates - Electric

(Entergy Gulf States Louisiana)

In November 2011 the LPSC approved a one-year extension of Entergy Gulf States Louisiana’s formula rate plan.  In May 2012, Entergy Gulf States Louisiana made its formula rate plan filing with the LPSC for the 2011 test year.  The filing reflected an 11.94% earned return on common equity, which is above the earnings bandwidth and would indicate a $6.5 million cost of service rate decrease was necessary under the formula rate plan.  The filing also reflected a $22.9 million rate decrease for the incremental capacity rider.  Subsequently, in August 2012, Entergy Gulf States Louisiana submitted a revised filing that reflected an earned return on common equity of 11.86% indicating a $5.7 million cost of service rate decrease is necessary under the formula rate plan.  The revised filing also indicates that a reduction of $20.3 million should be reflected in the incremental capacity rider.  The rate reductions were implemented, subject to refund, effective for bills rendered the first billing cycle of September 2012.  Subsequently, in December 2012, Entergy Gulf States Louisiana submitted a revised evaluation report that reflects expected retail jurisdictional cost of $16.9 million for the first-year capacity charges for the purchase from Entergy Louisiana of one-third of Acadia Unit 2 capacity and energy.  This rate change was implemented effective with the first billing cycle of January 2013.  The 2011 test year filings, as revised, were approved by the LPSC in February 2013.  In April 2013, Entergy Gulf States Louisiana submitted a revised evaluation report increasing the incremental capacity rider by approximately $7.3 million to reflect the cost of an additional capacity contract.

See Note 2 to the financial statements in the Form 10-K for a discussion of the base rate case filed by Entergy Gulf States Louisiana with the LPSC in February 2013.  In April 2013 the LPSC established a procedural schedule providing for hearings in November 2013, with a decision by the LPSC expected in 2014.  On July 26, 2013, with the concurrence of Entergy Gulf States Louisiana based upon an expected 60-day delay of the procedural schedule, the ALJ suspended the procedural schedule pending resolution of the appeal by Entergy Gulf States Louisiana, Entergy Louisiana and the LPSC staff regarding the ALJ’s denial of a motion to consolidate the rate cases of Entergy Gulf States Louisiana and Entergy Louisiana.  At an August 2013 meeting the LPSC rejected the proposed consolidation.  The base rate case is currently scheduled for an evidentiary hearing in February 2014.  An extension of the deadline for the filing of the staff’s and intervenors’ testimony was granted to allow for settlement negotiations, which are ongoing.

(Entergy Louisiana)

In November 2011 the LPSC approved a one-year extension of Entergy Louisiana’s formula rate plan.  In May 2012, Entergy Louisiana made its formula rate plan filing with the LPSC for the 2011 test year.  The filing reflected a 9.63% earned return on common equity, which is within the earnings bandwidth and results in no cost of service rate change under the formula rate plan.  The filing also reflected an $18.1 million rate increase for incremental capacity costs.  In August 2012, Entergy Louisiana submitted a revised filing that reflects an earned return on common equity of 10.38%, which is still within the earnings bandwidth, resulting in no cost of service rate change.  The revised filing also indicates that an increase of $15.9 million should be reflected in the incremental capacity rider.  The rate change was implemented, subject to refund, effective for bills rendered the first billing cycle of September 2012.  Subsequently, in December 2012, Entergy Louisiana submitted a revised evaluation report that reflects two items: 1) a $17 million reduction for the first-year capacity charges for the purchase by Entergy Gulf States Louisiana from Entergy Louisiana of one-third of Acadia Unit 2 capacity and energy, and 2) an $88 million increase for the first-year retail revenue requirement associated with the Waterford 3 replacement steam generator project, which was in-service in December 2012.  These rate changes were implemented, subject to refund, effective with the first billing cycle of January 2013.  In April 2013, Entergy Louisiana and the LPSC staff filed a joint report resolving the 2011 test year formula rate plan and recovery related to the Grand Gulf uprate.  This report was approved by the LPSC in April 2013.  With completion of the Waterford 3 replacement steam generator project, the LPSC is conducting a prudence review in connection with a filing made by Entergy Louisiana in April 2013 with regard to the following aspects of the replacement project: 1) project management; 2) cost controls; 3) success in achieving stated objectives; 4) the costs of the replacement project; and 5) the outage length and replacement power costs.  A procedural schedule for the prudence review has not yet been established.
 
 
39

Entergy Corporation and Subsidiaries
Notes to Financial Statements



See Note 2 to the financial statements in the Form 10-K for a discussion of the base rate case filed by Entergy Louisiana with the LPSC in February 2013.  In April 2013 the LPSC established a procedural schedule providing for hearings in December 2013, with a decision by the LPSC expected in 2014.  On July 26, 2013, with the concurrence of Entergy Louisiana based upon an expected 60-day delay of the procedural schedule, the ALJ suspended the procedural schedule pending resolution of the appeal by Entergy Gulf States Louisiana, Entergy Louisiana and the LPSC staff regarding the ALJ’s denial of a motion to consolidate the rate cases of Entergy Gulf States Louisiana and Entergy Louisiana.  At an August 2013 meeting the LPSC rejected the proposed consolidation.  A new procedural schedule was established calling for an evidentiary hearing in December 2013.  Entergy Louisiana submitted an opposed motion to modify the procedural schedule to allow for settlement negotiations, which are ongoing.  The motion was granted and the evidentiary hearing has been rescheduled to occur in January 2014.

Retail Rates - Gas (Entergy Gulf States Louisiana)

In January 2013, Entergy Gulf States Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2012.  The filing showed an earned return on common equity of 11.18%, which resulted in a $43 thousand rate reduction.  In March 2013 the LPSC Staff issued its proposed findings and recommended two adjustments.  The first is to normalize property insurance expense, and the second is to modify the return on equity for gas operations to reflect the return on equity that ultimately is approved by the LPSC in the investigation previously initiated by the LPSC to review the return on equity for Louisiana gas utilities.  Entergy Gulf States Louisiana and the LPSC Staff reached agreement regarding the LPSC Staff’s proposed adjustments.  As reflected in an unopposed joint report of proceedings filed by Entergy Gulf States Louisiana and the LPSC Staff on May 16, 2013, Entergy Gulf States Louisiana accepted, with modification, the LPSC Staff’s proposed adjustment to property insurance expense and agreed to: (1) a three-year extension of the gas rate stabilization plan with a midpoint return on equity of 9.95%, with a first year midpoint reset; (2) dismissal of the docket initiated by the LPSC to evaluate the allowed return on equity for Entergy Gulf States Louisiana’s gas rate stabilization plan; and (3) presentation to the LPSC by November 2014 by Entergy Gulf States Louisiana and the LPSC Staff of their recommendation for implementation of an infrastructure rider to recover expenditures associated with strategic plant investment.  The LPSC approved the agreement in May 2013.

Filings with the MPSC (Entergy Mississippi)

Formula Rate Plan Filings

In March 2013, Entergy Mississippi submitted its formula rate plan 2012 test year filing.  The filing requested a $36.3 million revenue increase to reset Entergy Mississippi's return on common equity to 10.55%, which is a point within the formula rate plan bandwidth.  On June 6, 2013, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation, in which both parties agreed that the MPSC should approve a $22.3 million rate increase for Entergy Mississippi which, with other adjustments reflected in the stipulation, would have the effect of resetting Entergy Mississippi’s return on common equity to 10.59% when adjusted for performance under the formula rate plan.  In August 2013 the MPSC approved the joint stipulation between Entergy Mississippi and the Mississippi Public Utilities Staff authorizing the rate increase effective with September 2013 bills.  Additionally, the MPSC authorized Entergy Mississippi to defer approximately $1.2 million in MISO-related implementation costs incurred in 2012 along with other MISO-related implementation costs to be incurred in 2013.

Filings with the City Council

(Entergy Louisiana)

In March 2013, Entergy Louisiana filed a rate case for the Algiers area, which is in New Orleans and is regulated by the City Council.  Entergy Louisiana is requesting a rate increase of $13 million over three years, including a 10.4% return on common equity and a formula rate plan mechanism identical to its LPSC request.  Hearings are scheduled for April 2014.  New rates are currently expected to become effective in second quarter 2014.
 
 
40

Entergy Corporation and Subsidiaries
Notes to Financial Statements



(Entergy New Orleans)

As discussed in the Form 10-K, in May 2012, Entergy New Orleans filed its electric and gas formula rate plan evaluation reports for the 2011 test year.   In August 2013 the City Council unanimously approved a settlement of all issues in the formula rate plan proceeding.  Pursuant to the terms of the settlement, Entergy New Orleans  implemented an approximately $1.625 million net decrease to the electric rates that were in effect prior to the electric rate increase implemented in October 2012, with no change in gas rates.  Entergy New Orleans is in the process of refunding to customers approximately $6.0 million over the four-month period from September 2013 through December 2013 to make the electric rate decrease effective as of the first billing cycle of October 2012.  Entergy New Orleans had previously recorded provisions for the majority of the refund to customers, but recorded an additional $1.1 million provision in second quarter 2013 as a result of the settlement.

Filings with the PUCT (Entergy Texas)

2013 Rate Case

In September 2013, Entergy Texas filed a rate case requesting a $38.6 million base rate increase reflecting a 10.4% return on common equity based on an adjusted test year ending March 31, 2013.  The rate case also proposed (1) a rough production cost equalization adjustment rider recovering Entergy Texas’s payment to Entergy New Orleans to achieve rough production cost equalization based on calendar year 2012 production costs, (2) a rate case expense rider recovering the cost of the 2013 rate case and certain costs associated with previous rate cases, and (3) a transmission cost recovery factor rider recovering any differences in transmission costs and rate mitigation compared to those included in base rates to the extent the proposed spin-merge transaction with ITC Holdings Corp. is completed.  The rate case filing also includes a request to reconcile $0.9 billion of fuel and purchased power costs and fuel revenues covering the period July 2011 through March 2013.  The fuel reconciliation also reflects special circumstances fuel cost recovery of approximately $22 million of purchased power capacity costs.  A procedural schedule has been set that includes staff testimony due in December 2013 and hearings in January 2014.  If approved, new rates could go into effect as early as April 2014.

System Agreement Cost Equalization Proceedings

See Note 2 to the financial statements in the Form 10-K for a discussion of the proceedings regarding the System Agreement.  Following are updates to that discussion.

Rough Production Cost Equalization Rates

2007 Rate Filing Based on Calendar Year 2006 Production Costs

See Note 2 to the financial statements in the Form 10-K for a discussion of this proceeding.  On October 16, 2013, the FERC issued two orders related to this proceeding.   The first order provided clarification with regard to the derivation of the ratio that should be used to functionalize net operating loss carryforwards for purposes of the annual bandwidth filings.  The second order denied Entergy’s request for rehearing of the FERC’s prior determination that interest should be included on recalculated payment and receipt amounts required in this particular proceeding due to the length of time that had passed.

2008 Rate Filing Based on Calendar Year 2007 Production Costs

See Note 2 to the financial statements in the Form 10-K for a discussion of this proceeding.  In March 2013 the LPSC filed a petition for review with the U.S. Court of Appeals for the Fifth Circuit seeking appellate review of the FERC’s earlier orders addressing the ALJ’s initial decision.


 
41

Entergy Corporation and Subsidiaries
Notes to Financial Statements


2009 Rate Filing Based on Calendar Year 2008 Production Costs

See Note 2 to the financial statements in the Form 10-K for a discussion of this proceeding.  In January 2013 the LPSC filed a protest of Entergy’s July 2012 compliance filing submitted in response to the FERC’s May 2012 order.  On October 16, 2013, the FERC issued orders denying the LPSC’s rehearing request with respect to the FERC’s May 2012 order and addressing Entergy's compliance filing implementing the FERC’s directives in the May 2012 order.  The compliance filing order referred to guidance provided in a separate order issued on that same day in the 2007 rate proceeding with respect to the ratio used to functionalize net operating loss carryforwards for bandwidth purposes and directed Entergy to make an additional compliance filing in the 2009 rate proceeding consistent with the guidance provided in that order.

2010 Rate Filing Based on Calendar Year 2009 Production Costs

See Note 2 to the financial statements in the Form 10-K for a discussion of this proceeding.  On October 16, 2013, the FERC issued an order granting clarification and denying rehearing with respect to its October 6, 2011 rehearing order in this proceeding.   The FERC clarified that in a bandwidth proceeding parties can challenge erroneous inputs, implementation errors, or prudence of cost inputs, but challenges to the bandwidth formula itself must be raised in a Federal Power Act section 206 complaint or section 205 filing.   On October 18, 2013, the presiding ALJ lifted the stay order holding in abeyance the hearing previously ordered by the FERC and directing that the remaining issues proceed to a hearing on the merits.

It is probable that the October 2013 orders disclosed above will result in a reallocation of payments/receipts among the Utility operating companies to achieve production cost equalization as defined by the FERC orders.  There is still significant uncertainty, however, as to the amount and allocation of these payments/receipts.  This uncertainty relates to other pending orders associated with these rate filings, potential requests for further clarification from the FERC regarding the issued orders, and Entergy’s legal strategy going forward.  Any payments required by the Utility operating companies as a result of these rate filings are expected to be recoverable from customers, and any receipts are expected to be credited to customers.  The effect of any such payments or receipts is not expected to be material to the results of operations, financial position or cash flows of Entergy or the Utility operating companies.

2013 Rate Filing Based on Calendar Year 2012 Production Costs

In May 2013, Entergy filed with the FERC the 2013 rates in accordance with the FERC’s orders in the System Agreement proceeding.  The filing shows the following payments/receipts among the Utility operating companies for 2013, based on calendar year 2012 production costs, commencing for service in June 2013, are necessary to achieve rough production cost equalization under the FERC’s orders:

 
Payments or
(Receipts)
 
(In Millions)
Entergy Arkansas
$-
Entergy Gulf States Louisiana
$-
Entergy Louisiana
$-
Entergy Mississippi
$-
Entergy New Orleans
($15)
Entergy Texas
$15

Several parties intervened in the proceeding at the FERC, including the LPSC, which filed a protest as well.  The City Council intervened and filed comments related to including the outcome of a related FERC proceeding in the 2013 cost equalization calculation.  On August 31, 2013, FERC issued an order accepting the 2013 rates, effective June 1, 2013, subject to refund, set the proceeding for hearing procedures, and then held those procedures in abeyance pending FERC decisions in the prior production cost proceedings currently before the FERC on review.


 
42

Entergy Corporation and Subsidiaries
Notes to Financial Statements


Interruptible Load Proceeding

See Note 2 to the financial statements in the Form 10-K for a discussion of the proceeding regarding the treatment under the System Agreement of the Utility operating companies’ interruptible loads.  On March 21, 2013, the FERC issued an order denying the LPSC's request for rehearing of the FERC's June 2011 order wherein the FERC concluded it would exercise its discretion and not order refunds in the interruptible load proceeding.  Based on its review of the LPSC’s request for rehearing and the briefs filed as part of the paper hearing established in October 2011, the FERC affirmed its earlier ruling and declined to order refunds under the circumstances of the case.  On May 2, 2013, the LPSC filed a petition for review with the U.S. Court of Appeals for the D.C. Circuit seeking review of FERC’s prior orders in the Interruptible Load Proceeding concluding that it would exercise its discretion and not order refunds in the proceeding.  The appeal is pending.

Storm Cost Recovery Filings with Retail Regulators

Entergy Gulf States Louisiana and Entergy Louisiana

Hurricane Isaac

See Note 2 to the financial statements in the Form 10-K for a discussion of Hurricane Isaac and the damage caused to portions of Entergy’s service area in Louisiana.  In January 2013, Entergy Gulf States Louisiana and Entergy Louisiana withdrew $65 million and $187 million, respectively, from their storm reserve escrow accounts.  In April 2013, Entergy Gulf States Louisiana and Entergy Louisiana filed a joint application with the LPSC relating to Hurricane Isaac system restoration costs.  Specifically, Entergy Gulf States Louisiana and Entergy Louisiana requested that the LPSC determine the amount of such costs that were prudently incurred and are, thus, eligible for recovery from customers.  Including carrying costs and additional storm escrow funds, Entergy Gulf States Louisiana is seeking an LPSC determination that $73.8 million in system restoration costs were prudently incurred and Entergy Louisiana is seeking an LPSC determination that $247.7 million in system restoration costs were prudently incurred.  Entergy Gulf States Louisiana and Entergy Louisiana intend to replenish their storm escrow accounts to $90 million and $200 million, respectively, primarily through traditional debt markets and have requested special rate treatment of any borrowings for that purpose.  In May 2013, Entergy Gulf States Louisiana and Entergy Louisiana filed a supplemental application proposing a specific means to finance system restoration costs and related requests.  Entergy Gulf States Louisiana and Entergy Louisiana are proposing to finance Hurricane Isaac restoration costs through Louisiana Act 55 financing, which was the same method they used for Hurricanes Katrina, Rita, Gustav, and Ike.

The LPSC Staff filed direct testimony in September 2013 concluding that Hurricane Isaac system restoration costs incurred by Entergy Gulf States Louisiana and Entergy Louisiana were reasonable and prudent, subject to proposed minor adjustments which totaled approximately 1% of each company’s costs.  The LPSC Staff also supported the requests to re-establish storm reserves of $90 million for Entergy Gulf States Louisiana and $200 million for Entergy Louisiana.  One intervenor filed testimony recommending storm reserve levels of $70 million for Entergy Gulf States Louisiana and $100 million for Entergy Louisiana, but takes no position on the prudence of the Hurricane Isaac system restoration costs.  An evidentiary hearing is scheduled in December 2013, with an LPSC decision expected in 2014.

Entergy Mississippi

On July 1, 2013, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation, wherein both parties agreed that approximately $32 million in storm restoration costs incurred in 2011 and 2012 were prudently incurred and chargeable to the storm damage reserve, while approximately $700,000 in prudently incurred costs were more properly recoverable through the formula rate plan.  Entergy Mississippi and the Mississippi Public Utilities Staff also agreed that the storm damage accrual should be increased from $750,000 per month to $1.75 million per month.  In September 2013 the MPSC approved the joint stipulation with the increase in the storm damage accrual effective with October 2013 bills.
 
 

 
43

Entergy Corporation and Subsidiaries
Notes to Financial Statements


Texas Power Price Lawsuit

See Note 2 to the financial statements in the Form 10-K for a discussion of the lawsuit filed in August 2003 in the district court of Chambers County, Texas by Texas residents on behalf of a purported class of the Texas retail customers of Entergy Gulf States, Inc. who were billed and paid for electric power from January 1, 1994 to the present.  The case is pending in state district court, and in March 2012 the court found that the case met the requirements to be maintained as a class action under Texas law.  In April 2012 the court entered an order certifying the class.  The defendants have appealed the order to the Texas Court of Appeals – First District.  The appeal is pending, and proceedings in district court are stayed until the appeal is resolved.  Oral arguments before the court of appeals were conducted on April 23, 2013, and the matter awaits that court’s decision.

Entergy Arkansas Opportunity Sales Proceeding

See Note 2 to the financial statements in the Form 10-K for a discussion of the Entergy Arkansas opportunity sales proceeding.  As required by the procedural schedule established in the calculation proceeding, Entergy filed its direct testimony that included a proposed illustrative re-run, consistent with the directives in FERC’s order, of intra-system bills for 2003, 2004, and 2006, the three years with the highest volume of opportunity sales.  Entergy’s proposed illustrative re-run of intra-system bills shows that the potential cost for Entergy Arkansas would be up to $12 million for the years 2003, 2004, and 2006, and the potential benefit would be significantly less than that for each of the other Utility operating companies.  Entergy’s proposed illustrative re-run of the intra-system bills also shows an offsetting potential benefit to Entergy Arkansas for the years 2003, 2004, and 2006 resulting from the effects of the FERC’s order on System Agreement Service Schedules MSS-1, MSS-2, and MSS-3, and the potential offsetting cost would be significantly less than that for each of the other Utility operating companies.  Entergy provided to the LPSC an illustrative intra-system bill recalculation as specified by the LPSC for the years 2003, 2004, and 2006, and the LPSC then filed answering testimony in December 2012.  In its testimony the LPSC claims that the damages that should be paid by Entergy Arkansas to the other Utility operating companies’ customers for 2003, 2004, and 2006 are $42 million to Entergy Gulf States, Inc., $7 million to Entergy Louisiana, $23 million to Entergy Mississippi, and $4 million to Entergy New Orleans.  The FERC staff and certain intervenors filed direct and answering testimony in February 2013.  In April 2013, Entergy filed its rebuttal testimony in that proceeding, including a revised illustrative re-run of the intra-system bills for the years 2003, 2004, and 2006.  The revised calculation determines the re-pricing of the opportunity sales based on consideration of moveable resources only and the removal of exchange energy received by Entergy Arkansas, which increases the potential cost for Entergy Arkansas over the three years 2003, 2004, and 2006 by $2.3 million from the potential costs identified in the Utility operating companies’ prior filings in September and October 2012.  A hearing was held in May 2013 to quantify the effect of repricing the opportunity sales in accordance with the FERC’s decision.

In August 2013 the presiding judge issued an initial decision.  The initial decision concludes that the methodology proposed by the LPSC, rather than the methodologies proposed by Entergy or the FERC Staff, should be used to calculate the payments that Entergy Arkansas is to make to the other Utility operating companies.  The initial decision also concludes that the other System Agreement service schedules should not be adjusted and that payments by Entergy Arkansas should not be reflected in the rough production cost equalization bandwidth calculations for the applicable years.  The initial decision does recognize that the LPSC’s methodology would result in an inequitable windfall to the other Utility operating companies and, therefore, concludes that any payments by Entergy Arkansas should be reduced by 20%.  The Utility operating companies are currently analyzing the effects of the initial decision.  The initial decision and record in the case have been forwarded to the FERC for review.  The LPSC, APSC, City Council, and FERC staff filed briefs on exceptions and/or briefs opposing exceptions.  Entergy filed a brief on exceptions requesting that FERC reverse the initial decision and a brief opposing certain exceptions taken by the LPSC and FERC staff.  The FERC’s review of the initial decision is pending.   No payments will be made or received by the Utility operating companies until the FERC issues an order reviewing the initial decision and Entergy submits a subsequent filing to comply with that order.



 
44

Entergy Corporation and Subsidiaries
Notes to Financial Statements


NOTE 3.  EQUITY  (Entergy Corporation, Entergy Gulf States Louisiana, and Entergy Louisiana)

Common Stock

Earnings 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 September 30,
   
2013
 
2012
   
(In Millions, Except Per Share Data)
                         
Basic earnings per share
 
Income
 
Shares
 
$/share
 
Income
 
Shares
 
$/share
                         
Net income attributable to
Entergy Corporation
 
 
$239.9
 
 
178.3
 
 
$1.35
 
 
$337.1
 
 
177.5
 
 
$1.90
Average dilutive effect of:
                       
Stock options
     
0.1
 
     
0.4
 
(0.01)
Other equity plans
     
0.3
 
(0.01)
 
 
 
0.1
 
 - 
                         
Diluted earnings per share
 
$239.9
 
178.7
 
$1.34 
 
$337.1
 
178.0
 
$1.89
   
 
For the Nine Months Ended September 30,
   
2013
 
2012
   
(In Millions, Except Per Share Data)
                         
Basic earnings per share
 
Income
 
Shares
 
$/share
 
Income
 
Shares
 
$/share
                         
Net income attributable to
Entergy Corporation
 
 
$565.0
 
 
178.2
 
 
$3.17 
 
 
$550.4
 
 
177.2
 
 
$3.11
Average dilutive effect of:
                       
Stock options
     
0.1
 
     
0.3
 
(0.01)
Other equity plans
     
0.2
 
(0.01)
 
 
 
0.1
 
 - 
                         
Diluted earnings per share
 
$565.0
 
178.5
 
$3.16 
 
$550.4
 
177.6
 
$3.10

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 8.8 million and 6.2 million for the third quarters of 2013 and 2012, respectively.  The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 8.9 million and 7.7 million for the nine months ended September 30, 2013 and 2012, respectively.

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

Treasury Stock

During the nine months ended September 30, 2013, Entergy Corporation issued 498,426 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 nine months ended September 30, 2013.
 
 
45

Entergy Corporation and Subsidiaries
Notes to Financial Statements


Retained Earnings

On October 25, 2013, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.83 per share, payable on December 2, 2013 to holders of record as of November 7, 2013.

Comprehensive Income

Accumulated other comprehensive loss is included in the equity section of the balance sheets of Entergy, Entergy Gulf States Louisiana, and Entergy Louisiana.  The following table presents changes in accumulated other comprehensive loss for Entergy for the three months ended September 30, 2013 by component:

 
Cash flow
hedges
net
unrealized
gain (loss)
 
Pension
and
other
postretirement
liabilities
 
 
Net
unrealized
investment
gains
 
 
 
Foreign
currency
translation
 
Total
Accumulated
Other
Comprehensive
Loss
 
(In Thousands)
                   
Beginning balance, June 30, 2013
$31,520 
 
($571,138)
 
$262,891 
 
$2,424 
 
($274,303)
                   
Other comprehensive income (loss)
before reclassifications
 
(9,838)
 
 
 
 
45,647
 
 
706 
 
 
36,515 
Amounts reclassified from
accumulated other comprehensive
loss
 
 
(21,825)
 
 
 
15,430 
 
 
 
653
 
 
 
 
 
 
(5,742) 
Net other comprehensive income (loss)
for the period
 
(31,663)
 
 
15,430 
 
 
46,300
 
 
706 
 
 
30,773 
                   
Ending balance, September 30, 2013
($143)
 
($555,708)
 
$309,191 
 
$3,130 
 
($243,530)

The following table presents changes in accumulated other comprehensive loss for Entergy for the nine months ended September 30, 2013 by component:

 
Cash flow
hedges
net
unrealized
gain (loss)
 
Pension
and
other
postretirement
liabilities
 
 
Net
unrealized
investment
gains
 
 
 
Foreign
currency
translation
 
Total
Accumulated
Other
Comprehensive
Loss
 
(In Thousands)
                   
Beginning balance, December 31, 2012
$79,905 
 
($590,712)
 
$214,547 
 
$3,177 
 
($293,083)
                   
Other comprehensive income (loss)
before reclassifications
 
(57,376)
 
 
 
 
95,843 
 
 
(47)
 
 
38,420 
Amounts reclassified from
accumulated other comprehensive
loss
 
 
(22,672)
 
 
 
35,004 
 
 
 
(1,199)
 
 
 
 
 
 
11,133 
Net other comprehensive income (loss)
for the period
 
(80,048)
 
 
35,004 
 
 
94,644 
 
 
(47)
 
 
49,553 
                   
Ending balance, September 30, 2013
($143)
 
($555,708)
 
$309,191  
 
$3,130 
 
($243,530)

 
 
46

Entergy Corporation and Subsidiaries
Notes to Financial Statements



The following table presents changes in accumulated other comprehensive loss for Entergy Gulf States Louisiana and Entergy Louisiana for the three months ended September 30, 2013:

   
Pension and Other
Postretirement Liabilities
   
Entergy
Gulf States
Louisiana
 
 
Entergy
Louisiana
   
(In Thousands)
         
Beginning balance June 30, 2013
 
($63,312)
 
($44,771)
         
Amounts reclassified from accumulated other
comprehensive income
 
 
963 
 
 
684 
Net other comprehensive income for the period
 
963 
 
684 
         
Ending balance, September 30, 2013
 
($62,349)
 
($44,087)

The following table presents changes in accumulated other comprehensive loss for Entergy Gulf States Louisiana and Entergy Louisiana for the nine months ended September 30, 2013:

   
Pension and Other
Postretirement Liabilities
   
Entergy
Gulf States
Louisiana
 
 
Entergy
Louisiana
   
(In Thousands)
         
Beginning balance, December 31, 2012
 
($65,229)
 
($46,132)
         
Amounts reclassified from accumulated other
comprehensive income
 
 
2,880 
 
 
2,045 
Net other comprehensive income for the period
 
2,880 
 
2,045 
         
Ending balance, September 30, 2013
 
($62,349)
 
($44,087)


 
47

Entergy Corporation and Subsidiaries
Notes to Financial Statements


Total reclassifications out of accumulated other comprehensive loss (AOCI) for Entergy for the three months ended September 30, 2013 are as follows:

   
Amounts
reclassified
from
AOCI
 
 
 
 
Income Statement Location
   
(In Thousands)
   
         
Cash flow hedges net unrealized gain
       
Power contracts
 
$35,325 
 
Competitive business operating revenues
Interest rate swaps
 
(389)
 
Miscellaneous - net
Total realized gains on cash flow hedges
 
34,936 
   
   
(13,111)
 
Income taxes
Total realized gains on cash flow hedges (net of tax)
 
$21,825 
   
         
Pension and other postretirement liabilities
       
Amortization of prior-service costs
 
$2,414 
 
(a)
Amortization of loss
 
(17,179)
 
(a)
Curtailment loss
 
(1,304)
 
(a)
Settlement loss
 
(9,662)
 
(a)
Total amortization
 
(25,731)
   
   
10,301 
 
Income taxes
Total amortization (net of tax)
 
($15,430)
   
         
Net unrealized investment loss
       
Realized loss
 
($1,280)
 
Interest and investment income
   
627 
 
Income taxes
Total realized investment loss (net of tax)
 
($653)
   
         
Total reclassifications for the period (net of tax)
 
$5,742 
   

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


 
48

Entergy Corporation and Subsidiaries
Notes to Financial Statements


Total reclassifications out of accumulated other comprehensive loss (AOCI) for Entergy for the nine months ended September 30, 2013 are as follows:
 
   
Amounts
reclassified
from
AOCI
 
 
 
 
Income Statement Location
   
(In Thousands)
   
         
Cash flow hedges net unrealized gain
       
Power contracts
 
$37,518 
 
Competitive business operating revenues
Interest rate swaps
 
(1,193)
 
Miscellaneous - net
Total realized gains  on cash flow hedges
 
36,325 
   
   
(13,653)
 
Income taxes
Total realized gains on cash flow hedges (net of tax)
 
$22,672 
   
         
Pension and other postretirement liabilities
       
Amortization of prior-service costs
 
7,175 
 
(a)
Amortization of loss
 
(53,268)
 
(a)
Curtailment loss
 
(1,304)
 
(a)
Settlement loss
 
(9,662)
 
(a)
Total amortization
 
(57,059)
   
   
22,055 
 
Income taxes
Total amortization (net of tax)
 
($35,004)
   
         
Net unrealized investment gains
       
Realized gains
 
$2,351 
 
Interest and investment income
   
(1,152)
 
Income taxes
Total realized investment gains (net of tax)
 
$1,199 
   
         
Total reclassifications for the period (net of tax)
 
($11,133)
   

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

Total reclassifications out of accumulated other comprehensive loss (AOCI) for Entergy Gulf States Louisiana and Entergy Louisiana for the three months ended September 30, 2013 are as follows:

   
Amounts reclassified
from AOCI
   
   
Entergy
Gulf States
Louisiana
 
 
Entergy
Louisiana
 
 
 
Income Statement Location
   
(In Thousands)
   
             
Pension and other postretirement liabilities
           
Amortization of prior-service costs
 
$206 
 
$62 
 
(a)
Amortization of loss
 
(1,947)
 
(1,288)
 
(a)
Total amortization
 
(1,741)
 
(1,226)
   
   
778 
 
542 
 
Income taxes
Total amortization (net of tax)
 
(963)
 
(684)
   
             
Total reclassifications for the period (net of tax)
 
($963)
 
($684)
   

(a)
These accumulated other comprehensive loss components are included in the computation of net periodic pension cost.  See Note 6 to the financial statements for additional details.
 
 
49

Entergy Corporation and Subsidiaries
Notes to Financial Statements


Total reclassifications out of accumulated other comprehensive loss (AOCI) for Entergy Gulf States Louisiana and Entergy Louisiana for the nine months ended September 30, 2013 are as follows:

   
Amounts reclassified
from AOCI
   
   
Entergy
Gulf States
Louisiana
 
 
Entergy
Louisiana
 
 
 
Income Statement Location
   
(In Thousands)
   
             
Pension and other postretirement liabilities
           
Amortization of prior-service costs
 
$617 
 
$186 
 
(a)
Amortization of loss
 
(5,839)
 
(3,862)
 
(a)
Total amortization
 
(5,222)
 
(3,676)
   
   
2,342 
 
1,631 
 
Income taxes
Total amortization (net of tax)
 
(2,880)
 
(2,045)
   
             
Total reclassifications for the period (net of tax)
 
($2,880)
 
($2,045)
   

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


NOTE 4.  REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, 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 March 2018.  Entergy Corporation also has the ability to issue letters of credit against 50% of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.275% 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 nine months ended September 30, 2013 was 1.96% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2013:

 
Capacity (a)
 
 
Borrowings
 
Letters
of Credit
 
Capacity
Available
(In Millions)
             
$3,500
 
$150
 
$8
 
$3,342

(a)
The capacity decreases to $3,490 million in March 2017.

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

Entergy Corporation has a commercial paper program with a program limit of up to $1.5 billion.  As of September 30, 2013, Entergy Corporation had approximately $1,016 million of commercial paper outstanding.  The weighted-average interest rate for the nine months ended September 30, 2013 was 0.83%.


 
50

Entergy Corporation and Subsidiaries
Notes to Financial Statements


Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2013 as follows:

 
 
 
Company
 
 
 
Expiration
Date
 
 
 
Amount of
Facility
 
 
 
 
Interest Rate (a)
 
Amount Drawn
as of
September 30,
2013
                 
Entergy Arkansas
 
April 2014
 
$20 million (b)
 
1.75%
 
$-
Entergy Arkansas
 
March 2018
 
$150 million (c)
 
1.68%
 
$-
Entergy Gulf States Louisiana
 
March 2018
 
$150 million (d)
 
1.68%
 
$-
Entergy Louisiana
 
March 2018
 
$200 million (e)
 
1.68%
 
$-
Entergy Mississippi
 
May 2014
 
$37.5 million (f)
 
1.93%
 
$-
Entergy Mississippi
 
May 2014
 
$35 million (f)
 
1.93%
 
$-
Entergy Mississippi
 
May 2014
 
$20 million (f)
 
1.93%
 
$-
Entergy New Orleans
 
November 2013
 
$25 million (g)
 
1.65%
 
$-
Entergy Texas
 
March 2018
 
$150 million (h)
 
1.93%
 
$-


(a)
The interest rate is the rate as of September 30, 2013 that would most likely apply to outstanding borrowings under the facility.
(b)
The credit facility requires Entergy Arkansas to maintain a debt ratio of 65% or less of its total capitalization.  Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable.
(c)
The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility.  As of September 30, 2013, no letters of credit were outstanding.  The credit facility requires Entergy Arkansas to maintain a consolidated debt ratio of 65% or less of its total capitalization.
(d)
The credit facility allows Entergy Gulf States Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility.  As of September 30, 2013, no letters of credit were outstanding.  The credit facility requires Entergy Gulf States Louisiana to maintain a consolidated debt ratio of 65% or less of its total capitalization.
(e)
The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility.  As of September 30, 2013, no letters of credit were outstanding.  The credit facility requires Entergy Louisiana to maintain a consolidated debt ratio of 65% or less of its total capitalization.
(f)
The credit facilities require Entergy Mississippi to maintain a debt ratio of 65% or less of its total capitalization.  Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable.
(g)
The credit facility requires Entergy New Orleans to maintain a debt ratio of 65% or less of its total capitalization.  In October 2013, Entergy New Orleans renewed its credit facility through November 2014.
(h)
The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility.  As of September 30, 2013, no letters of credit were outstanding.  The credit facility requires Entergy Texas to maintain a consolidated debt ratio of 65% or less of its total capitalization.

The commitment fees on the credit facilities range from 0.125% to 0.275% of the undrawn commitment amount.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized limits are effective through October 31, 2015.  In addition to borrowings from commercial banks, these companies are authorized under a FERC order to borrow from the Entergy System money pool.  The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from the money pool and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2013 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries:

 
51

Entergy Corporation and Subsidiaries
Notes to Financial Statements





   
Authorized
 
Borrowings
   
(In Millions)
         
Entergy Arkansas
 
$250
 
$-
Entergy Gulf States Louisiana
 
$200
 
$58
Entergy Louisiana
 
$250
 
$-
Entergy Mississippi
 
$175
 
$19
Entergy New Orleans
 
$100
 
$-
Entergy Texas
 
$200
 
$-
System Energy
 
$200
 
$-

Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy have obtained long-term financing authorizations from the FERC that extend through October 31, 2015.  Entergy Arkansas has obtained long-term financing authorization from the APSC that extends through December 2015.  Entergy New Orleans has obtained long-term financing authorization from the City Council that extends through July 2014.

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

See Note 18 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIE).  The nuclear fuel company variable interest entities have credit facilities and also issue commercial paper to finance the acquisition and ownership of nuclear fuel as follows as of September 30, 2013:

 
 
 
 
 
Company
 
 
 
 
 
Expiration
Date
 
 
 
 
Amount
of
Facility
 
Weighted
Average
Interest
Rate on
Borrowings
(a)
 
 
Amount
Outstanding
as of
September 30,
2013
   
(Dollars in Millions)
                 
Entergy Arkansas VIE
 
June 2016
 
$85
 
1.63%
 
$20.1 
Entergy Gulf States Louisiana VIE
 
June 2016
 
$100
 
1.50%
 
$31.0 
Entergy Louisiana VIE
 
June 2016
 
$90
 
1.58%
 
$24.3 
System Energy VIE
 
June 2016
 
$125
 
1.57%
 
$46.5 

(a)
Includes letter of credit fees and bank fronting fees on commercial paper issuances 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 Gulf States Louisiana does not issue commercial paper but borrows directly on its bank credit facility.

Amounts outstanding on the Entergy Gulf States Louisiana nuclear fuel company variable interest entity’s credit facility, if any, are included in long-term debt on its balance sheet and commercial paper outstanding for the other nuclear fuel company variable interest entities is classified as a current liability on the respective balance sheets.  The commitment fees on the credit facilities are 0.125% of the undrawn commitment amount.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio of 70% or less of its total capitalization.


 
52

Entergy Corporation and Subsidiaries
Notes to Financial Statements


The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2013 as follows:

Company
 
Description
 
Amount
         
Entergy Arkansas VIE
 
5.69% Series I due July 2014
 
$70 million
Entergy Arkansas VIE
 
3.23% Series J due July 2016
 
$55 million
Entergy Arkansas VIE
 
2.62% Series K due December 2017
 
$60 million
Entergy Gulf States Louisiana VIE
 
3.25% Series Q due July 2017
 
$75 million
Entergy Gulf States Louisiana VIE
 
3.38% Series R due August 2020
 
$70 million
Entergy Louisiana VIE
 
5.69% Series E due July 2014
 
$50 million
Entergy Louisiana VIE
 
3.30% Series F due March 2016
 
$20 million
Entergy Louisiana VIE
 
3.25% Series G due July 2017
 
$25 million
System Energy VIE
 
5.33% Series G due April 2015
 
$60 million
System Energy VIE
 
4.02% Series H due February 2017
 
$50 million

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

Debt Issuances and Redemptions

(Entergy Arkansas)

In January 2013, Entergy Arkansas arranged for the issuance by (i) Independence County, Arkansas of $45 million of 2.375% Pollution Control Revenue Refinancing Bonds (Entergy Arkansas, Inc. Project) Series 2013 due January 2021, and (ii) Jefferson County, Arkansas of $54.7 million of 1.55% Pollution Control Revenue Refunding Bonds (Entergy Arkansas, Inc. Project) Series 2013 due October 2017, each of which series is secured by a separate series of non-interest bearing first mortgage bonds of Entergy Arkansas.  The proceeds of these issuances were applied to the refunding of outstanding series of pollution control revenue bonds previously issued by the respective issuers.

In May 2013, Entergy Arkansas issued $250 million of 3.05% Series first mortgage bonds due June 2023. Entergy Arkansas used the proceeds to pay, at maturity, a portion of its $300 million 5.40% Series first mortgage bonds due August 2013 and for general corporate purposes.

In June 2013, Entergy Arkansas issued $125 million of 4.75% Series first mortgage bonds due June 2063. Entergy Arkansas used the proceeds to pay, at maturity, a portion of its $300 million 5.40% Series first mortgage bonds due August 2013 and for general corporate purposes.

In June 2013 the Entergy Arkansas nuclear fuel company variable interest entity redeemed, at maturity, its $30 million 9% Series H notes.

In July 2013, Entergy Arkansas entered into a $250 million term loan credit facility terminating January 26, 2015 with the collateral support of a series of $255 million non-interest bearing Entergy Arkansas first mortgage bonds.  On July 31, 2013, Entergy Arkansas borrowed $250 million against the credit facility.  Entergy Arkansas used the borrowings to pay, at maturity, a portion of its $300 million 5.40% Series first mortgage bonds due August 2013 and for general corporate purposes.

(Entergy Gulf States Louisiana)

In February 2013 the Entergy Gulf States Louisiana nuclear fuel company variable interest entity issued $70 million of 3.38% Series R notes due August 2020.  The Entergy Gulf States Louisiana nuclear fuel company variable interest entity used the proceeds primarily to purchase additional nuclear fuel.

In May 2013 the Entergy Gulf States Louisiana nuclear fuel company variable interest entity redeemed, at maturity, its $75 million 5.56% Series N notes.
 
 
53

Entergy Corporation and Subsidiaries
Notes to Financial Statements


(Entergy Louisiana)

In May 2013, Entergy Louisiana issued $100 million of 4.70% Series first mortgage bonds due June 2063. Entergy Louisiana used the proceeds for general corporate purposes.

In August 2013, Entergy Louisiana issued $325 million of 4.05% Series first mortgage bonds due September 2023.  Entergy Louisiana used the proceeds to repay borrowings under its $200 million credit facility and for general corporate purposes

(Entergy Mississippi)

In February 2013, Entergy Mississippi redeemed, at maturity, its $100 million 5.15% Series first mortgage bonds.

In October 2013, Entergy Mississippi redeemed, prior to maturity, its $16.03 million 4.60% Series pollution control revenue bonds due April 2022.

(Entergy New Orleans)

In June 2013, Entergy New Orleans issued $100 million of 3.90% Series first mortgage bonds due July 2023.  Entergy New Orleans used the proceeds to pay, at maturity, its $70 million 5.25% Series first mortgage bonds due August 2013 and for general corporate purposes.

(System Energy Resources)

In September 2013 the System Energy Resources nuclear fuel company variable interest entity redeemed, at maturity, its $70 million 6.29% Series F notes.

In October 2013 the System Energy Resources nuclear fuel company variable interest entity issued $85 million of 3.78% Series I notes due October 2018.  The System Energy nuclear fuel company variable interest entity used the proceeds to repay outstanding commercial paper and to purchase additional nuclear fuel.

Fair Value

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2013 are as follows:

   
Book Value
of Long-Term Debt
 
Fair Value
of Long-Term Debt (a) (b)
   
(In Thousands)
         
Entergy
 
$12,481,752
 
$12,294,254 
Entergy Arkansas
 
$2,412,168
 
$2,159,737 
Entergy Gulf States Louisiana
 
$1,543,608
 
$1,605,999 
Entergy Louisiana
 
$3,229,316
 
$3,184,097 
Entergy Mississippi
 
$1,069,627
 
$1,083,993 
Entergy New Orleans
 
$225,942
 
$220,675 
Entergy Texas
 
$1,567,566
 
$1,736,764 
System Energy
 
$672,406
 
$576,502 

(a)
The values exclude lease obligations of $149 million at Entergy Louisiana and $97 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $112 million at Entergy, and include debt due within one year.
(b)
Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements and are based on prices derived from inputs such as benchmark yields and reported trades.

 
54

Entergy Corporation and Subsidiaries
Notes to Financial Statements


The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2012 were as follows:

   
Book Value
of Long-Term Debt
 
Fair Value
of Long-Term Debt (a) (b)
   
(In Thousands)
         
Entergy
 
$12,638,834
 
$12,849,330
Entergy Arkansas
 
$2,123,895
 
$1,876,335
Entergy Gulf States Louisiana
 
$1,517,429
 
$1,668,819
Entergy Louisiana
 
$2,826,095
 
$2,921,322
Entergy Mississippi
 
$1,169,519
 
$1,230,714
Entergy New Orleans
 
$196,300
 
$200,725
Entergy Texas
 
$1,617,813
 
$1,885,672
System Energy
 
$783,799
 
$664,670

(a)
The values exclude lease obligations of $163 million at Entergy Louisiana and $139 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $110 million at Entergy, and include debt due within one year.
(b)
Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements and are based on prices derived from inputs such as benchmark yields and reported trades.


NOTE 5.  STOCK-BASED COMPENSATION (Entergy Corporation)

Entergy grants stock 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.

Stock Options

Entergy granted 600,700 stock options during the first quarter 2013 with a weighted-average fair value of $8.00 per option.  At September 30, 2013, there are 9,521,281 stock options outstanding with a weighted-average exercise price of $80.10.  The intrinsic value, which has no effect on net income, of the outstanding stock options is calculated by the difference in the weighted average exercise price of the stock options granted and Entergy Corporation’s common stock price as of September 30, 2013.  Because Entergy’s stock price at September 30, 2013 is less than the weighted average exercise price, the aggregate intrinsic value of the stock options outstanding as of September 30, 2013 is zero.  The intrinsic value of “in the money” stock options is $3.1 million as of September 30, 2013.

The following table includes financial information for stock options for the third quarters of 2013 and 2012:

 
2013
 
2012
 
(In Millions)
       
Compensation expense included in Entergy’s net income
$1.0
 
$1.9
Tax benefit recognized in Entergy’s net income
$0.4
 
$0.7
Compensation cost capitalized as part of fixed assets and inventory
$0.2
 
$0.3


 
55

Entergy Corporation and Subsidiaries
Notes to Financial Statements


The following table includes financial information for stock options for the nine months ended September 30, 2013 and 2012:

 
2013
 
2012
 
(In Millions)
       
Compensation expense included in Entergy’s net income
$3.2
 
$5.8
Tax benefit recognized in Entergy’s net income
$1.3
 
$2.2
Compensation cost capitalized as part of fixed assets and inventory
$0.6
 
$1.1

Other Equity Plans

In January 2013 the Board approved and Entergy granted 361,700 restricted stock awards and 201,474 long-term incentive awards under the 2011 Equity Ownership and Long-term Cash Incentive Plan.  The restricted stock awards were made effective as of January 31, 2013 and were valued at $64.60 per share, which was the closing price of Entergy’s common stock on that date.  One-third of the restricted stock awards will vest upon each anniversary of the grant date.  The long-term incentive awards are granted in the form of performance units, which are equal to the cash value of shares of Entergy Corporation at the end of the performance period, which is the last day of the year.  The performance units were made effective as of January 31, 2013 and were valued at $65.36 per share.  Entergy considers various factors, primarily market conditions, in determining the value of the performance units.  Shares of the restricted stock awards 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.  Shares of the performance units have the same dividend 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.

The following table includes financial information for other equity plans for the third quarters of 2013 and 2012:

 
2013
 
2012
 
(In Millions)
       
Compensation expense included in Entergy’s net income
$5.7
 
$3.7
Tax benefit recognized in Entergy’s net income
$2.2
 
$1.4
Compensation cost capitalized as part of fixed assets and inventory
$0.9
 
$0.6

 The following table includes financial information for other equity plans for the nine months ended September 30, 2013 and 2012:

 
2013
 
2012
 
(In Millions)
       
Compensation expense included in Entergy’s net income
$17.5
 
$11.0
Tax benefit recognized in Entergy’s net income
$6.8
 
$4.2
Compensation cost capitalized as part of fixed assets and inventory
$2.7
 
$1.9



 
56

Entergy Corporation and Subsidiaries
Notes to Financial Statements


NOTE 6.  RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, 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 third quarters of 2013 and 2012, included the following components:

   
2013
 
2012
   
(In Thousands)
         
Service cost - benefits earned during the period
 
$43,542 
 
$37,691 
Interest cost on projected benefit obligation
 
65,464 
 
65,232 
Expected return on assets
 
(81,898)
 
(79,356)
Amortization of prior service cost
 
531 
 
683 
Amortization of loss
 
54,156 
 
41,820 
Curtailment loss
 
1,304 
 
Net pension costs
 
$83,099 
 
$66,070 

Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2013 and 2012, included the following components:

   
2013
 
2012
   
(In Thousands)
         
Service cost - benefits earned during the period
 
$131,644 
 
$113,073 
Interest cost on projected benefit obligation
 
195,996 
 
195,696 
Expected return on assets
 
(245,394)
 
(238,068)
Amortization of prior service cost
 
1,665 
 
2,049 
Amortization of loss
 
164,058 
 
125,460 
Curtailment loss
 
1,304 
 
Net pension costs
 
$249,273 
 
$198,210 

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2013 and 2012, included the following components:

 
 
2013
 
 
Entergy
Arkansas
 
Entergy
Gulf States
Louisiana
 
 
Entergy
Louisiana
 
 
Entergy
 Mississippi
 
 
Entergy
New Orleans
 
 
Entergy
Texas
 
 
System
Energy
   
(In Thousands)
Service cost - benefits earned
                           
  during the period
 
$6,371 
 
$3,599 
 
$4,334 
 
$1,842 
 
$832 
 
$1,637 
 
$1,836 
Interest cost on projected
                           
  benefit obligation
 
13,550 
 
6,657 
 
8,644 
 
3,930 
 
1,849
 
4,055 
 
3,016 
Expected return on assets
 
(16,717)
 
(8,734)
 
(10,454)
 
(5,279)
 
(2,270)
 
(5,566)
 
(4,299)
Amortization of prior service
                           
  cost
 
 
 
21 
 
 
 
 
Amortization of loss
 
12,544 
 
5,933 
 
8,727 
 
3,344 
 
2,011 
 
3,373 
 
2,429 
Net pension cost
 
$15,754 
 
$7,457 
 
$11,272 
 
$3,839 
 
$2,422 
 
$3,501 
 
$2,985 


 
57

Entergy Corporation and Subsidiaries
Notes to Financial Statements



 
 
2012
 
 
Entergy
Arkansas
 
Entergy
Gulf States
Louisiana
 
 
Entergy
Louisiana
 
 
Entergy
 Mississippi
 
 
Entergy
New Orleans
 
 
Entergy
Texas
 
 
System
Energy
   
(In Thousands)
Service cost - benefits earned
                           
  during the period
 
$5,542 
 
$3,068 
 
$3,669 
 
$1,602 
 
$706 
 
$1,421 
 
$1,480 
Interest cost on projected
                           
  benefit obligation
 
13,922 
 
6,420 
 
8,800 
 
4,070 
 
1,902
 
4,206 
 
3,247 
Expected return on assets
 
(16,441)
 
(8,593)
 
(10,209)
 
(5,236)
 
(2,215)
 
(5,581)
 
(4,109)
Amortization of prior service
                           
  cost
 
50 
 
 
52 
 
 
 
 
Amortization of loss
 
10,193 
 
4,043 
 
7,050 
 
2,633 
 
1,719 
 
2,544 
 
2,251 
Net pension cost
 
$13,266 
 
$4,943 
 
$9,362 
 
$3,076 
 
$2,114 
 
$2,594 
 
$2,872 

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2013 and 2012, included the following components:

 
 
2013
 
 
Entergy
Arkansas
 
Entergy
Gulf States
Louisiana
 
 
Entergy
Louisiana
 
 
Entergy
 Mississippi
 
 
Entergy
New Orleans
 
 
Entergy
Texas
 
 
System
Energy
   
(In Thousands)
Service cost - benefits earned
                           
  during the period
 
$19,113 
 
$10,797 
 
$13,002 
 
$5,526 
 
$2,496 
 
$4,911 
 
$5,508 
Interest cost on projected
                           
  benefit obligation
 
40,650 
 
19,971 
 
25,932 
 
11,790 
 
5,547
 
12,165 
 
9,048 
Expected return on assets
 
(50,151)
 
(26,202)
 
(31,362)
 
(15,837)
 
(6,810)
 
(16,698)
 
(12,897)
Amortization of prior service
                           
  cost
 
18 
 
 
63 
 
 
 
 
Amortization of loss
 
37,631 
 
17,800 
 
26,181 
 
10,032 
 
6,033 
 
10,118 
 
7,286 
Net pension cost
 
$47,261 
 
$22,372 
 
$33,816 
 
$11,517 
 
$7,266 
 
$10,502 
 
$8,954 


 
 
2012
 
 
Entergy
Arkansas
 
Entergy
Gulf States
Louisiana
 
 
Entergy
Louisiana
 
 
Entergy
 Mississippi
 
 
Entergy
New Orleans
 
 
Entergy
Texas
 
 
System
Energy
   
(In Thousands)
Service cost - benefits earned
                           
  during the period
 
$16,626 
 
$9,204 
 
$11,007 
 
$4,806 
 
$2,118 
 
$4,263 
 
$4,440 
Interest cost on projected
                           
  benefit obligation
 
41,766 
 
19,260 
 
26,400 
 
12,210 
 
5,706 
 
12,618 
 
9,741 
Expected return on assets
 
(49,323)
 
(25,779)
 
(30,627)
 
(15,708)
 
(6,645)
 
(16,743)
 
(12,327)
Amortization of prior service
                           
  cost
 
150 
 
15 
 
156 
 
21 
 
 
12 
 
Amortization of loss
 
30,579 
 
12,129 
 
21,150 
 
7,899 
 
5,157 
 
7,632 
 
6,753 
Net pension cost
 
$39,798 
 
$14,829 
 
$28,086 
 
$9,228 
 
$6,342 
 
$7,782 
 
$8,616 


 
 
58

Entergy Corporation and Subsidiaries
Notes to Financial Statements


Non-Qualified Net Pension Cost

Entergy recognized $33.1 million and $5.1 million in pension cost for its non-qualified pension plans in the third quarters of 2013 and 2012, respectively, and $44.1 million and $15.3 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2013 and 2012, respectively.  Reflected in the pension cost for non-qualified pension plans in the third quarter 2013 and nine months ended September 30, 2013 is a $28.1 million settlement charge recognized in September 2013 related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans in the third quarters of 2013 and 2012:

   
 
Entergy
Arkansas
 
Entergy
Gulf States
Louisiana
 
 
Entergy
Louisiana
 
 
Entergy
Mississippi
 
 
Entergy
New Orleans
 
 
Entergy
Texas
   
(In Thousands)
Non-qualified pension cost
 third quarter 2013
 
 
$121
 
 
$38
 
 
$3
 
 
$46
 
 
$22
 
 
$560
Non-qualified pension cost
 third quarter 2012
 
 
$107
 
 
$39
 
 
$3
 
 
$46
 
 
$19
 
 
$163

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2013 and 2012:

   
 
Entergy
Arkansas
 
Entergy
Gulf States
Louisiana
 
 
Entergy
Louisiana
 
 
Entergy
Mississippi
 
 
Entergy
New Orleans
 
 
Entergy
Texas
   
(In Thousands)
Non-qualified pension cost
 nine months ended
 September 30, 2013
 
 
 
$326
 
 
 
$113
 
 
 
$9
 
 
 
$139
 
 
 
$68
 
 
 
$857
Non-qualified pension cost
 nine months ended
 September 30, 2012
 
 
 
$321
 
 
 
$117
 
 
 
$9
 
 
 
$138
 
 
 
$57
 
 
 
$489

Reflected in Entergy Arkansas’s and Entergy Texas’s non-qualified pension costs in the third quarter 2013 and nine months ended September 30, 2013 are $19 thousand and $415 thousand, respectively, in settlement charges recognized in September 2013 related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefit Cost

Entergy’s other postretirement benefit cost, including amounts capitalized, for the third quarters of 2013 and 2012, included the following components:

   
2013
 
2012
   
(In Thousands)
         
Service cost - benefits earned during the period
 
$18,917 
 
$17,221 
Interest cost on accumulated postretirement benefit
     obligation (APBO)
 
 
19,766 
 
 
20,640 
Expected return on assets
 
(9,950)
 
(8,626)
Amortization of transition obligation
 
 
794 
Amortization of prior service cost
 
(3,334)
 
(4,541)
Amortization of loss
 
11,304 
 
9,113 
Net other postretirement benefit cost
 
$36,703 
 
$34,601 


 
59

Entergy Corporation and Subsidiaries
Notes to Financial Statements


Entergy’s other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2013 and 2012, included the following components:

   
2013
 
2012
   
(In Thousands)
         
Service cost - benefits earned during the period
 
$56,751 
 
$51,663 
Interest cost on accumulated postretirement benefit
     obligation (APBO)
 
 
59,298 
 
 
61,920 
Expected return on assets
 
(29,850)
 
(25,878)
Amortization of transition obligation
 
 
2,382 
Amortization of prior service cost
 
(10,002)
 
(13,623)
Amortization of loss
 
33,912 
 
27,339 
Net other postretirement benefit cost
 
$110,109 
 
$103,803 

The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the third quarters of 2013 and 2012, included the following components:

 
 
2013
 
 
Entergy
Arkansas
 
Entergy
Gulf States
Louisiana
 
 
Entergy
Louisiana
 
 
Entergy
Mississippi
 
 
Entergy
New Orleans
 
 
Entergy
Texas
 
 
System
Energy
   
(In Thousands)
Service cost - benefits earned
                           
  during the period
 
$2,414 
 
$2,001 
 
$2,172 
 
$819 
 
$447 
 
$950 
 
$907 
Interest cost on APBO
 
3,360 
 
2,226 
 
2,349 
 
1,074 
 
785 
 
1,515 
 
729 
Expected return on assets
 
(4,149)
 
 
 
(1,317)
 
(1,014)
 
(2,321)
 
(825)
Amortization of prior service
                           
  cost
 
(133)
 
(206)
 
(62)
 
(35)
 
10 
 
(107)
 
(16)
Amortization of loss
 
2,041 
 
1,173 
 
1,288 
 
662 
 
396 
 
976 
 
479 
Net other postretirement
                           
  benefit cost
 
$3,533 
 
$5,194 
 
$5,747 
 
$1,203 
 
$624 
 
$1,013 
 
$1,274 

 
 
2012
 
 
Entergy
Arkansas
 
Entergy
Gulf States
Louisiana
 
 
Entergy
Louisiana
 
 
Entergy
Mississippi
 
 
Entergy
New Orleans
 
 
Entergy
Texas
 
 
System
Energy
   
(In Thousands)
Service cost - benefits earned
                           
  during the period
 
$2,272 
 
$1,880 
 
$1,949 
 
$773 
 
$422 
 
$913 
 
$823 
Interest cost on APBO
 
3,613 
 
2,398 
 
2,445 
 
1,179 
 
856 
 
1,663 
 
757 
Expected return on assets
 
(3,507)
 
 
 
(1,130)
 
(928)
 
(2,104)
 
(650)
Amortization of transition
                           
  obligation
 
205 
 
60 
 
96 
 
88 
 
297 
 
47 
 
Amortization of prior service
                           
  cost
 
(133)
 
(206)
 
(62)
 
(35)
 
10 
 
(107)
 
(16)
Amortization of loss
 
2,077 
 
1,184 
 
1,090 
 
730 
 
390 
 
1,079 
 
493 
Net other postretirement
                           
  benefit cost
 
$4,527 
 
$5,316 
 
$5,518 
 
$1,605 
 
$1,047 
 
$1,491 
 
$1,409 



 
60

Entergy Corporation and Subsidiaries
Notes to Financial Statements


The Registrant Subsidiaries’ other postretirement benefit cost, including amounts capitalized, for their employees for the nine months ended September 30, 2013 and 2012, included the following components:

 
 
2013
 
 
Entergy
Arkansas
 
Entergy
Gulf States
Louisiana
 
 
Entergy
Louisiana
 
 
Entergy
Mississippi
 
 
Entergy
New Orleans
 
 
Entergy
Texas
 
 
System
Energy
   
(In Thousands)
Service cost - benefits earned
                           
  during the period
 
$7,242 
 
$6,003 
 
$6,516 
 
$2,457 
 
$1,341 
 
$2,850 
 
$2,721 
Interest cost on APBO
 
10,080 
 
6,678 
 
7,047 
 
3,222 
 
2,355 
 
4,545 
 
2,187 
Expected return on assets
 
(12,447)
 
 
 
(3,951)
 
(3,042)
 
(6,963)
 
(2,475)
Amortization of prior service
                           
  cost
 
(399)
 
(618)
 
(186)
 
(105)
 
30 
 
(321)
 
(48)
Amortization of loss
 
6,124 
 
3,520 
 
3,862 
 
1,987 
 
1,189 
 
2,927 
 
1,437 
Net other postretirement
                           
  benefit cost
 
$10,600 
 
$15,583 
 
$17,239 
 
$3,610 
 
$1,873 
 
$3,038 
 
$3,822 

 
 
2012
 
 
Entergy
Arkansas
 
Entergy
Gulf States
Louisiana
 
 
Entergy
Louisiana
 
 
Entergy
Mississippi
 
 
Entergy
New Orleans
 
 
Entergy
Texas
 
 
System
Energy
   
(In Thousands)
Service cost - benefits earned
                           
  during the period
 
$6,816 
 
$5,640 
 
$5,847 
 
$2,319 
 
$1,266 
 
$2,739 
 
$2,469 
Interest cost on APBO
 
10,839 
 
7,194 
 
7,335 
 
3,537 
 
2,568 
 
4,989 
 
2,271 
Expected return on assets
 
(10,521)
 
 
 
(3,390)
 
(2,784)
 
(6,312)
 
(1,950)
Amortization of transition
                           
  obligation
 
615 
 
180 
 
288 
 
264 
 
891 
 
141 
 
Amortization of prior service
                           
  cost
 
(399)
 
(618)
 
(186)
 
(105)
 
30 
 
(321)
 
(48)
Amortization of loss
 
6,231 
 
3,552 
 
3,270 
 
2,190 
 
1,170 
 
3,237 
 
1,479 
Net other postretirement
                           
  benefit cost
 
$13,581 
 
$15,948 
 
$16,554 
 
$4,815 
 
$3,141 
 
$4,473 
 
$4,227 


 
61

Entergy Corporation and Subsidiaries
Notes to Financial Statements


Reclassification out of Accumulated Other Comprehensive Income

Entergy and the Registrant Subsidiaries reclassified the following costs out of accumulated other comprehensive income (before taxes and including amounts capitalized) for the third quarter 2013:

   
Qualified
Pension
Costs
 
Other
Postretirement
Costs
 
Non-Qualified
Pension Costs
 
 
 
Total
   
(In Thousands)
   
Entergy
               
Amortization of prior service cost
 
($466)
 
$3,007 
 
($127)
 
$2,414 
Amortization of loss
 
(11,050)
 
(5,485)
 
(644)
 
(17,179)
Curtailment loss
 
(1,304)
 
 
 
(1,304)
Settlement loss
 
 
 
(9,662)
 
(9,662)
   
($12,820)
 
($2,478)
 
($10,433)
 
($25,731)
                 
Entergy Gulf States Louisiana
               
Amortization of prior service cost
 
$- 
 
$206 
 
$- 
 
$206 
Amortization of loss
 
(772)
 
(1,173)
 
(2)
 
(1,947)
   
($772)
 
($967)
 
($2)
 
($1,741)
Entergy Louisiana
               
Amortization of prior service cost
 
$- 
 
$62 
 
$- 
 
$62 
Amortization of loss
 
 
(1,288)
 
 
(1,288)
   
$- 
 
($1,226)
 
$- 
 
($1,226)

Entergy and the Registrant Subsidiaries reclassified the following costs out of accumulated other comprehensive income (before taxes and including amounts capitalized) for the nine months ended September 30, 2013:

   
Qualified
Pension
Costs
 
Other
Postretirement
Costs
 
Non-Qualified
Pension Costs
   
 
 
Total
   
(In Thousands)
     
Entergy
                 
Amortization of prior service cost
 
($1,472)
 
$9,022 
 
($375)
   
$7,175 
Amortization of loss
 
(34,740)
 
(16,455)
 
(2,073)
   
(53,268)
Curtailment loss
 
(1,304)
 
 
   
(1,304)
Settlement loss
 
 
 
(9,662)
   
(9,662)
   
($37,516)
 
($7,433)
 
($12,110)
   
($57,059)
                   
Entergy Gulf States Louisiana
                 
Amortization of prior service cost
 
($1)
 
$618 
 
$- 
   
$617 
Amortization of loss
 
(2,314)
 
(3,520)
 
(5)
   
(5,839)
   
($2,315)
 
($2,902)
 
($5)
   
($5,222)
Entergy Louisiana
                 
Amortization of prior service cost
 
$- 
 
$186 
 
$- 
   
$186 
Amortization of loss
 
 
(3,862)
 
   
(3,862)
   
$- 
 
($3,676)
 
$- 
   
($3,676)


 
62

Entergy Corporation and Subsidiaries
Notes to Financial Statements


Employer Contributions

Based on current assumptions, Entergy expects to contribute $163.4 million to its qualified pension plans in 2013.  As of September 30, 2013, Entergy had contributed $105.8 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 2013:

   
 
Entergy
Arkansas
 
Entergy
Gulf States
Louisiana
 
 
Entergy
Louisiana
 
 
Entergy
Mississippi
 
 
Entergy
New Orleans
 
 
Entergy
Texas
 
 
System
Energy
   
(In Thousands)
Expected 2013 pension
  contributions
 
 
$35,382
 
 
$11,550
 
 
$21,151
 
 
$8,152
 
 
$4,175
 
 
$6,880
 
 
$8,304
Pension contributions made
  through September 2013
 
 
$21,729
 
 
$7,132
 
 
$13,343
 
 
$5,033
 
 
$2,634
 
 
$4,270
 
 
$5,175
Remaining estimated pension
  contributions to be made in 2013
 
 
$13,653
 
 
$4,418
 
 
$7,808
 
 
$3,119
 
 
$1,541
 
 
$2,610
 
 
$3,129


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

Entergy Corporation

Entergy’s reportable segments as of September 30, 2013 are Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership and operation of six nuclear power plants located in the northern United States and the sale of the electric power produced by those plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  “All Other” includes the parent company, Entergy Corporation, and other business activity, including the earnings on the proceeds of sales of previously-owned businesses.

In the fourth quarter 2012, Entergy moved two subsidiaries from All Other to the Entergy Wholesale Commodities segment to improve the alignment of certain intercompany items and income tax activity.  The 2012 information in the table below has been restated to reflect the change.

Entergy’s segment financial information for the third quarters of 2013 and 2012 is as follows:

 
 
 
Utility
 
Entergy
Wholesale
Commodities*
 
 
 
All Other
 
 
 
Eliminations
 
 
 
Entergy
 
(In Thousands)
2013
                 
Operating revenues
$2,732,482 
 
$623,321 
 
$787 
 
($4,631)
 
$3,351,959 
Income taxes
$170,816 
 
($107,337)
 
($38,926)
 
$- 
 
$24,553 
Consolidated net income (loss)
$352,303 
 
($92,828)
 
$11,102 
 
($26,395)
 
$244,182 
                   
2012
                 
Operating revenues
$2,344,885 
 
$626,849 
 
$1,060 
 
($9,234)
 
$2,963,560 
Income taxes
$187,668 
 
$56,676 
 
($11,841)
 
$- 
 
$232,503 
Consolidated net income (loss)
$300,506 
 
$86,772 
 
($18,213)
 
($26,395)
 
$342,670 
 
 
63

Entergy Corporation and Subsidiaries
Notes to Financial Statements


Entergy’s segment financial information for the nine months ended September 30, 2013 and 2012 is as follows:

 
 
 
Utility
 
Entergy
Wholesale
Commodities*
 
 
 
All Other
 
 
 
Eliminations
 
 
 
Entergy
 
(In Thousands)
2013
                 
Operating revenues
$6,948,258 
 
$1,770,577 
 
$2,775 
 
($22,569)
 
$8,699,041 
Income taxes
$340,817 
 
($64,968)
 
($61,647)
 
$- 
 
$214,202 
Consolidated net income (loss)
$680,694 
 
$818 
 
($23,107)
 
($79,185)
 
$579,220 
                   
2012
                 
Operating revenues
$6,136,101 
 
$1,754,774 
 
$3,027 
 
($28,082)
 
$7,865,820 
Income taxes
$162,914 
 
$11,427 
 
($64,201)
 
$- 
 
$110,140 
Consolidated net income (loss)
$676,244 
 
($18,420)
 
($11,487)
 
($79,824)
 
$566,513 

Businesses marked with * are sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity.

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 Gulf States Louisiana, 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 instrument or commodity.  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 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’s core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities enters into forward contracts with its customers and sells energy and capacity in the day ahead or spot markets.  In addition to its forward physical power contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, put and/or call options, to mitigate forward commodity price risk.  When market price falls, the combination of instruments is expected to settle in gains offsetting lower revenue from generation and resulting in a more predictable cash flow.


 
64

Entergy Corporation and Subsidiaries
Notes to Financial Statements


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.

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 will occasionally enter into financially settled swap and option contracts to manage market risk under certain hedging transactions which may or may not be designated as hedging instruments.

Entergy enters into derivatives only to manage natural risks inherent in its physical or financial assets or liabilities.  The maximum length of time over which Entergy is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2013 is approximately 2.25 years.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 82% for the remainder of 2013, of which approximately 59% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2013 is 11 TWh.

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Gulf States Louisiana, Entergy Louisiana, and Entergy New Orleans) and Entergy Mississippi primarily through the purchase of short-term natural gas swaps that financially settle against NYMEX futures.  These swaps are marked-to-market 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 for electric generation and projected winter purchases for gas distribution at Entergy Gulf States Louisiana and Entergy New Orleans.  The total volume of natural gas swaps outstanding as of September 30, 2013 is 19,081,000 MMBtu for Entergy, 7,600,000 MMBtu for Entergy Gulf States Louisiana, 8,540,000 MMBtu for Entergy Louisiana, 2,010,000 MMBtu for Entergy Mississippi, and 931,000 MMBtu for Entergy New Orleans.  Credit support for these natural gas swaps is covered by master agreements that do not require collateralization based on mark-to-market value, but do carry adequate assurance language that may lead to collateralization requests.


 
65

Entergy Corporation and Subsidiaries
Notes to Financial Statements


The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2013 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting arrangements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument
 
Balance Sheet Location
 
Fair Value (a)
 
Offset (b)
 
Net (c) (d)
 
Business
       
(In Millions)
   
                     
Derivatives designated as hedging instruments
                   
                     
Assets:
                   
Electricity swaps and options
 
Prepayments and other (current portion)
 
$50
 
($28)
 
$22
 
Entergy Wholesale Commodities
Electricity swaps and options
 
Other deferred debits and other assets (non-current portion)
 
$12
 
($7)
 
$5
 
Entergy Wholesale Commodities
                     
Liabilities:
                   
Electricity swaps and options
 
Other current liabilities
(current portion)
 
$40
 
($27)
 
$13
 
Entergy Wholesale Commodities
Electricity swaps and options
 
Other non-current liabilities (non-current portion)
 
$11
 
($7)
 
$4
 
Entergy Wholesale Commodities

Derivatives not designated as hedging instruments
                   
                     
Assets:
                   
Electricity swaps and options
 
Prepayments and other (current portion)
 
$78
 
($28)
 
$50
 
Entergy Wholesale Commodities
Electricity swaps and options
 
Other deferred debits and other assets (non-current portion)
 
$15
 
($7)
 
$8
 
Entergy Wholesale Commodities
                     
Liabilities:
                   
Electricity swaps and options
 
Other current liabilities
(current portion)
 
$39
 
($29)
 
$10
 
Entergy Wholesale Commodities
Electricity swaps and options
 
Other non-current liabilities (non-current portion)
 
$16
 
($7)
 
$9
 
Entergy Wholesale Commodities
Natural gas swaps
 
Other current liabilities
 
$3
 
($-)
 
$3
 
Utility


 
66

Entergy Corporation and Subsidiaries
Notes to Financial Statements


The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2012 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting arrangements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument
 
Balance Sheet Location
 
Fair Value (a)
 
Offset (b)
 
Net (c) (d)
 
Business
       
(In Millions)
   
                     
Derivatives designated as hedging instruments
                   
                     
Assets:
                   
Electricity swaps and options
 
Prepayments and other (current portion)
 
$123
 
($-)
 
$123
 
Entergy Wholesale Commodities
Electricity swaps and options
 
Other deferred debits and other assets (non-current portion)
 
$46
 
($10)
 
$36
 
Entergy Wholesale Commodities
                     
Liabilities:
                   
Electricity swaps and options
 
Other non-current liabilities (non-current portion)
 
$18
 
($11)
 
$7
 
Entergy Wholesale Commodities

Derivatives not designated as hedging instruments
                   
                     
Assets:
                   
Electricity swaps and options
 
Prepayments and other (current portion)
 
$22
 
($-)
 
$22
 
Entergy Wholesale Commodities
Electricity swaps and options
 
Other deferred debits and other assets (non-current portion)
 
$24
 
($14)
 
$10
 
Entergy Wholesale Commodities
                     
Liabilities:
                   
Electricity swaps and options
 
Other non-current liabilities (non-current portion)
 
$19
 
($13)
 
$6
 
Entergy Wholesale Commodities
Natural gas swaps
 
Other current liabilities
 
$8
 
($-)
 
$8
 
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 Consolidated Balance Sheets
(d)
Excludes cash collateral in the amounts of $7 million and $56 million held as of September 30, 2013 and December 31, 2012, respectively


 
67

Entergy Corporation and Subsidiaries
Notes to Financial Statements


The effect of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2013 and 2012 are as follows:

 
 
Instrument
 
Amount of loss
recognized in other
comprehensive income
 
 
 
Income Statement location
 
Amount of gain
 reclassified from
AOCI into income
             
2013
           
Electricity swaps and options
 
($4) million
 
Competitive businesses operating revenues
 
$35 million
             
2012
           
Electricity swaps and options
 
($108) million
 
Competitive businesses operating revenues
 
$61 million

The effect of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2013 and 2012 are as follows:

 
 
Instrument
 
Amount of gain (loss)
recognized in other
comprehensive income
 
 
 
Income Statement location
 
Amount of gain
 reclassified from
AOCI into income
             
2013
           
Electricity swaps and options
 
($78) million
 
Competitive businesses operating revenues
 
$38 million
             
2012
           
Electricity swaps and options
 
$120 million
 
Competitive businesses operating revenues
 
$232 million

Electricity over-the-counter instruments that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation.  Unrealized gains or losses recorded in other comprehensive income result from hedging power output at the Entergy Wholesale Commodities power plants.  The related gains or losses from hedging power are included in operating revenues when realized.  Gains totaling approximately $35 million and $61 million were realized on the maturity of cash flow hedges, before taxes of $13 million and $21 million, for the three months ended September 30, 2013 and 2012, respectively.  Gains totaling approximately $38 million and $232 million were realized on the maturity of cash flow hedges, before taxes of $14 million and $81 million, for the nine months ended September 30, 2013 and 2012, respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2013 and 2012 was ($1.8) million and ($1.2) million, respectively. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2013 and 2012 was ($2.3) million and ($1.6) million, respectively. The ineffective portion of cash flow hedges is recorded in competitive businesses operating revenues.

Based on market prices as of September 30, 2013, unrealized gains recorded in AOCI on cash flow hedges relating to power sales totaled $7 million of net unrealized gains.  Approximately $6 million is expected to be reclassified from AOCI to operating revenues in the next twelve months.  The actual amount reclassified from AOCI, however, could vary due to future changes in market prices.

Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide collateral to secure its obligations when the current market prices exceed the contracted power prices.  The primary form of collateral to satisfy these requirements is an Entergy Corporation guarantee.  As of September 30, 2013, hedge contracts with five counterparties were in a liability position (approximately $32 million total), but were significantly below the amount of the guarantee provided under the contract and no cash collateral was required. As of September 30, 2012, hedge contracts with one counterparty were in a
 
 
68

Entergy Corporation and Subsidiaries
Notes to Financial Statements


liability position (approximately $2 million total), but were significantly below the amount of the guarantee provided under the contract and no cash collateral was required. If the Entergy Corporation credit rating falls below investment grade, the effect of the corporate guarantee is typically ignored and Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.

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 settles. 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.

The effect of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2013 and 2012 is as follows:

 
Instrument
 
Amount of gain
recognized in AOCI
 
Income Statement
location
 
Amount of gain (loss)
recorded in income
             
2013
           
Natural gas swaps
 
$-
 
Fuel, fuel-related expenses, and gas purchased for resale
 
($1) million
Electricity swaps and options de-designated as hedged items
 
$4 million
 
Competitive business operating revenues
 
$12 million
             
2012
           
Natural gas swaps
 
$-
 
Fuel, fuel-related expenses, and gas purchased for resale
 
$7 million
Electricity swaps and options de-designated as hedged items
 
$3 million
 
Competitive business operating revenues
 
($7) million

The effect of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2013 and 2012 is as follows:

 
Instrument
 
Amount of gain
recognized in AOCI
 
Income Statement
location
 
Amount of gain (loss)
recorded in income
             
2013
           
Natural gas swaps
 
$-
 
Fuel, fuel-related expenses, and gas purchased for resale
 
$8 million
Electricity swaps and options de-designated as hedged items
 
$4 million
 
Competitive business operating revenues
 
$2 million
             
2012
           
Natural gas swaps
 
$-
 
Fuel, fuel-related expenses, and gas purchased for resale
 
($28) million
Electricity swaps and options de-designated as hedged items
 
$2 million
 
Competitive business operating revenues
 
($6) million
 
 
69

Entergy Corporation and Subsidiaries
Notes to Financial Statements



Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2013 are as follows:

Instrument
 
Balance Sheet Location
 
Fair Value
 
Registrant
             
Liabilities:
           
Natural gas swaps
 
Gas hedge contracts
 
$1.3 million
 
Entergy Gulf States Louisiana
Natural gas swaps
 
Gas hedge contracts
 
$1.4 million
 
Entergy Louisiana
Natural gas swaps
 
Other current liabilities
 
$0.3 million
 
Entergy Mississippi
Natural gas swaps
 
Other current liabilities
 
$0.2 million
 
Entergy New Orleans

The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2012 are as follows:

Instrument
 
Balance Sheet Location
 
Fair Value
 
Registrant
             
Liabilities:
           
Natural gas swaps
 
Gas hedge contracts
 
$2.6 million
 
Entergy Gulf States Louisiana
Natural gas swaps
 
Gas hedge contracts
 
$3.4 million
 
Entergy Louisiana
Natural gas swaps
 
Other current liabilities
 
$2.2 million
 
Entergy Mississippi

The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2013 and 2012 are as follows:

 
 
Instrument
 
 
 
Income Statement Location
 
Amount of gain
(loss) recorded
in income
 
 
 
Registrant
             
2013
           
Natural gas swaps
 
Fuel, fuel-related expenses, and gas purchased for resale
 
($0.4) million
 
Entergy Gulf States Louisiana
Natural gas swaps
 
Fuel, fuel-related expenses, and gas purchased for resale
 
($0.7) million
 
Entergy Louisiana
Natural gas swaps
 
Fuel, fuel-related expenses, and gas purchased for resale
 
($0.3) million
 
Entergy Mississippi
Natural gas swaps
 
Fuel, fuel-related expenses, and gas purchased for resale
 
($0.1) million
 
Entergy New Orleans
             
2012
           
Natural gas swaps
 
Fuel, fuel-related expenses, and gas purchased for resale
 
$2.0 million
 
Entergy Gulf States Louisiana
Natural gas swaps
 
Fuel, fuel-related expenses, and gas purchased for resale
 
$3.8 million
 
Entergy Louisiana
Natural gas swaps
 
Fuel, fuel-related expenses, and gas purchased for resale
 
$1.4 million
 
Entergy Mississippi


 
70

Entergy Corporation and Subsidiaries
Notes to Financial Statements


The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2013 and 2012 are as follows:

 
 
Instrument
 
 
 
Income Statement Location
 
Amount of gain
(loss) recorded
in income
 
 
 
Registrant
             
2013
           
Natural gas swaps
 
Fuel, fuel-related expenses, and gas purchased for resale
 
$2.4 million
 
Entergy Gulf States Louisiana
Natural gas swaps
 
Fuel, fuel-related expenses, and gas purchased for resale
 
$3.2 million
 
Entergy Louisiana
Natural gas swaps
 
Fuel, fuel-related expenses, and gas purchased for resale
 
$2.2 million
 
Entergy Mississippi
Natural gas swaps
 
Fuel, fuel-related expenses, and gas purchased for resale
 
($0.2) million
 
Entergy New Orleans
             
2012
           
Natural gas swaps
 
Fuel, fuel-related expenses, and gas purchased for resale
 
($8.3) million
 
Entergy Gulf States Louisiana
Natural gas swaps
 
Fuel, fuel-related expenses, and gas purchased for resale
 
($10.4) million
 
Entergy Louisiana
Natural gas swaps
 
Fuel, fuel-related expenses, and gas purchased for resale
 
($7.5) million
 
Entergy Mississippi
Natural gas swaps
 
Fuel, fuel-related expenses, and gas purchased for resale
 
($1.5) million
 
Entergy New Orleans

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not accrue to the benefit or detriment of shareholders.  Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.  The three levels of the fair value hierarchy are:

·  
Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas hedge contracts.  See Note 1 to the financial statements in the Form 10-K for a discussion of cash and cash equivalents.
 
 
 
71

Entergy Corporation and Subsidiaries
Notes to Financial Statements



 
·  
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 or shares in common trusts.  Common trust funds are stated at estimated fair value based on the fair market value of the underlying investments.

·  
Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of derivative power contracts used as cash flow hedges of power sales at merchant power plants.

The values for 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 Entergy Wholesale Commodities Risk Control Group and sent to the Entergy Wholesale Commodities Back Office and Entergy Nuclear Finance groups for evaluation.  The primary functions of the Entergy Wholesale Commodities Risk Control Group include: gathering, validating and reporting market data, providing market and credit risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market and credit risks, implementing and maintaining controls around changes to market data in the energy trading and risk management system, reviewing creditworthiness of counterparties, supporting contract negotiations with new counterparties, administering credit support for contracts, and managing the daily margining process.  The Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The primary functions of the Entergy Wholesale Commodities Back Office are market and counterparty settlements, revenue reporting and analysis and general ledger. The Entergy Wholesale Commodities Risk Control Group reports to the Vice President – Entergy Wholesale Commodities Chief Financial Officer while the Entergy Wholesale Commodities Back Office reports to the Controller, Competitive Operations.  Entergy Nuclear Finance is primarily responsible for the financial planning of Entergy’s utility and non-utility nuclear businesses. The VP, Chief Financial Officer – Nuclear Operations within Entergy Nuclear Finance 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.
 
 
 
72

Entergy Corporation and Subsidiaries
Notes to Financial Statements



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.  As of September 30, 2013, Entergy had in-the-money derivative contracts with a fair value of $85 million with counterparties or their guarantor who are all currently investment grade.  As of September 30, 2013, $36 million of the derivative contracts are out-of-the-money contracts supported by corporate guarantees, which would require additional cash or letters of credit in the event of a decrease in Entergy Corporation’s credit rating to below investment grade.

On a daily basis, Entergy Wholesale Commodities calculates the mark-to-market for all derivative transactions.  Entergy Wholesale Commodities Risk Control Group also validates forward market prices by comparing them to other sources of forward market prices and/or to settlement prices of actual market transactions.  Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices and/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 using multiple sources of market implied volatilities.  Moreover, on at least a monthly 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’s portfolio.  In particular, the credit, liquidity, and financial metrics impacts are calculated for this analysis.  This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2013 and December 31, 2012.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect their placement within the fair value hierarchy levels.

2013
 
Level 1
 
Level 2
 
Level 3
 
Total
   
(In Millions)
Assets:
               
Temporary cash investments
 
$262
 
$-
 
$-
 
$262
Decommissioning trust funds (a):
               
Equity securities
 
418
 
2,470
 
-
 
2,888
Debt securities
 
741
 
999
 
-
 
1,740
Power contracts
 
-
 
-
 
85
 
85
Securitization recovery trust account
 
50
 
-
 
-
 
50
Escrow accounts
 
135
 
-
 
-
 
135
   
$1,606
 
$3,469
 
$85
 
$5,160
                 
Liabilities:
               
Power contracts
 
$-
 
$-
 
$36
 
$36
Gas hedge contracts
 
3
 
-
 
-
 
3
   
$3
 
$-
 
$36
 
$39


 
73

Entergy Corporation and Subsidiaries
Notes to Financial Statements



2012
 
Level 1
 
Level 2
 
Level 3
 
Total
   
(In Millions)
Assets:
               
Temporary cash investments
 
$420
 
$-
 
$-
 
$420
Decommissioning trust funds (a):
               
Equity securities
 
358
 
2,101
 
-
 
2,459
Debt securities
 
769
 
962
 
-
 
1,731
Power contracts
 
-
 
-
 
191
 
191
Securitization recovery trust account
 
46
 
-
 
-
 
46
Escrow accounts
 
386
 
-
 
-
 
386
   
$1,979
 
$3,063
 
$191
 
$5,233
                 
Liabilities:
               
Power contracts
 
$-
 
$-
 
$13
 
$13
Gas hedge contracts
 
8
 
-
 
-
 
8
   
$8
 
$-
 
$13
 
$21

(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 for additional information on the investment portfolios.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2013 and 2012:

   
2013
 
2012
 
   
(In Millions)
           
Balance as of July 1,
 
$83 
 
$375 
 
           
Unrealized gains (losses) from price changes
 
 
(92)
 
Unrealized losses on originations
 
(1)
 
 
Realized losses included in earnings
 
(6)
 
(4)
 
Realized gains on settlements
 
(36)
 
(61)
 
           
Balance as of September 30,
 
$49 
 
$218 
 

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 nine months ended September 30, 2013 and 2012:

   
2013
 
2012
 
   
(In Millions)
           
Balance as of January 1,
 
$178 
 
$312 
 
           
Unrealized gains (losses) from price changes
 
(62)
 
136 
 
Unrealized gains on originations
 
 
 
Realized losses included in earnings
 
(29)
 
(5)
 
Realized gains on settlements
 
(38)
 
(232)
 
           
Balance as of September 30,
 
$49 
 
$218 
 
 
 
74

Entergy Corporation and Subsidiaries
Notes to Financial Statements



The following table sets forth a description of the types of transactions classified as Level 3 in the fair value hierarchy, and the valuation techniques and significant unobservable inputs to each which cause that classification, as of September 30, 2013:

 
 
 
Transaction Type
 
Fair Value
as of
September 30,
2013
 
 
 
Significant
Unobservable Inputs
 
Range
from
Average
%
 
 
 
Effect on
Fair Value
                 
Electricity swaps
 
$5 million
 
Unit contingent discount
 
+/-3%
 
$-
Electricity options
 
$44 million
 
Implied volatility
 
+/-40%
 
$27 million

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)
Implied volatility
 
Electricity options
 
Sell
 
Increase (Decrease)
 
Increase (Decrease)
Implied volatility
 
Electricity options
 
Buy
 
Increase (Decrease)
 
Increase (Decrease)

The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets that are accounted for at fair value on a recurring basis as of September 30, 2013 and December 31, 2012.  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

2013
 
Level 1
 
Level 2
 
Level 3
 
Total
   
(In Millions)
Assets:
               
Temporary cash investments
 
$41.7
 
$-
 
$-
 
$41.7
Decommissioning trust funds (a):
               
Equity securities
 
4.2
 
426.6
 
-
 
430.8
Debt securities
 
68.8
 
170.2
 
-
 
239.0
Securitization recovery trust account
 
7.9
 
-
 
-
 
7.9
Escrow accounts
 
38.0
 
-
 
-
 
38.0
   
$160.6
 
$596.8
 
$-
 
$757.4

2012
 
Level 1
 
Level 2
 
Level 3
 
Total
   
(In Millions)
Assets:
               
Temporary cash investments
 
$24.9
 
$-
 
$-
 
$24.9
Decommissioning trust funds (a):
               
Equity securities
 
9.5
 
374.5
 
-
 
384.0
Debt securities
 
94.3
 
122.3
 
-
 
216.6
Securitization recovery trust account
 
4.4
 
-
 
-
 
4.4
Escrow accounts
 
38.0
 
-
 
-
 
38.0
   
$171.1
 
$496.8
 
$-
 
$667.9

 
75

Entergy Corporation and Subsidiaries
Notes to Financial Statements


Entergy Gulf States Louisiana


2013
 
Level 1
 
Level 2
 
Level 3
 
Total
   
(In Millions)
Assets:
               
Temporary cash investments
 
$0.6
 
$-
 
$-
 
$0.6
Decommissioning trust funds (a):
               
Equity securities
 
5.6
 
341.6
 
-
 
347.2
Debt securities
 
53.3
 
137.1
 
-
 
190.4
Escrow accounts
 
21.5
 
-
 
-
 
21.5
   
$81.0
 
$478.7
 
$-
 
$559.7
                 
Liabilities:
               
Gas hedge contracts
 
$1.3
 
$-
 
$-
 
$1.3

2012
 
Level 1
 
Level 2
 
Level 3
 
Total
   
(In Millions)
Assets:
               
Temporary cash investments
 
$0.6
 
$-
 
$-
 
$0.6
Decommissioning trust funds (a):
               
Equity securities
 
5.5
 
283.0
 
-
 
288.5
Debt securities
 
49.5
 
139.4
 
-
 
188.9
Escrow accounts
 
87.0
 
-
 
-
 
87.0
   
$142.6
 
$422.4
 
$-
 
$565.0
                 
Liabilities:
               
Gas hedge contracts
 
$2.6
 
$-
 
$-
 
$2.6

Entergy Louisiana

2013
 
Level 1
 
Level 2
 
Level 3
 
Total
   
(In Millions)
Assets:
               
Temporary cash investments
 
$40.5
 
$-
 
$-
 
$40.5
Decommissioning trust funds (a):
               
Equity securities
 
4.6
 
210.1
 
-
 
214.7
Debt securities
 
51.8
 
58.9
 
-
 
110.7
Securitization recovery trust account
 
10.5
 
-
 
-
 
10.5
   
$107.4
 
$269.0
 
$-
 
$376.4
                 
Liabilities:
               
Gas hedge contracts
 
$1.4
 
$-
 
$-
 
$1.4


 
76

Entergy Corporation and Subsidiaries
Notes to Financial Statements



2012
 
Level 1
 
Level 2
 
Level 3
 
Total
   
(In Millions)
Assets:
               
Temporary cash investments
 
$29.3
 
$-
 
$-
 
$29.3
Decommissioning trust funds (a):
               
Equity securities
 
2.0
 
173.5
 
-
 
175.5
Debt securities
 
52.6
 
59.3
 
-
 
111.9
Securitization recovery trust account
 
4.4
 
-
 
-
 
4.4
Escrow accounts
 
187.0
 
-
 
-
 
187.0
   
$275.3
 
$232.8
 
$-
 
$508.1
                 
Liabilities:
               
Gas hedge contracts
 
$3.4
 
$-
 
$-
 
$3.4

Entergy Mississippi

2013
 
Level 1
 
Level 2
 
Level 3
 
Total
   
(In Millions)
Assets:
               
Escrow accounts
 
$61.8
 
$-
 
$-
 
$61.8
                 
Liabilities:
               
Gas hedge contracts
 
$0.3
 
$-
 
$-
 
$0.3

2012
 
Level 1
 
Level 2
 
Level 3
 
Total
   
(In Millions)
Assets:
               
Temporary cash investments
 
$52.4
 
$-
 
$-
 
$52.4
Escrow accounts
 
61.8
 
-
 
-
 
61.8
   
$114.2
 
$-
 
$-
 
$114.2
                 
Liabilities:
               
Gas hedge contracts
 
$2.2
 
$-
 
$-
 
$2.2

Entergy New Orleans

2013
 
Level 1
 
Level 2
 
Level 3
 
Total
   
(In Millions)
Assets:
               
Temporary cash investments
 
$14.4
 
$-
 
$-
 
$14.4
Escrow accounts
 
8.7
 
-
 
-
 
8.7
   
$23.1
 
$-
 
$-
 
$23.1
                 
Liabilities:
               
Gas hedge contracts
 
$0.2
 
$-
 
$-
 
$0.2


 
77

Entergy Corporation and Subsidiaries
Notes to Financial Statements



2012
 
Level 1
 
Level 2
 
Level 3
 
Total
   
(In Millions)
Assets:
               
Temporary cash investments
 
$9.1
 
$-
 
$-
 
$9.1
Escrow accounts
 
10.6
 
-
 
-
 
10.6
   
$19.7
 
$-
 
$-
 
$19.7

Entergy Texas

2013
 
Level 1
 
Level 2
 
Level 3
 
Total
   
(In Millions)
Assets:
               
Temporary cash investments
 
$19.7
 
$-
 
$-
 
$19.7
Securitization recovery trust account
 
31.4
 
-
 
-
 
31.4
   
$51.1
 
$-
 
$-
 
$51.1

2012
 
Level 1
 
Level 2
 
Level 3
 
Total
   
(In Millions)
Assets:
               
Temporary cash investments
 
$59.7
 
$-
 
$-
 
$59.7
Securitization recovery trust account
 
37.3
 
-
 
-
 
37.3
   
$97.0
 
$-
 
$-
 
$97.0

System Energy

2013
 
Level 1
 
Level 2
 
Level 3
 
Total
   
(In Millions)
Assets:
               
Temporary cash investment
 
$3.1
 
$-
 
$-
 
$3.1
Decommissioning trust funds (a):
               
Equity securities
 
1.0
 
342.8
 
-
 
343.8
Debt securities
 
151.6
 
68.0
 
-
 
219.6
   
$155.7
 
$410.8
 
$-
 
$566.5

2012
 
Level 1
 
Level 2
 
Level 3
 
Total
   
(In Millions)
Assets:
               
Temporary cash investments
 
$83.5
 
$-
 
$-
 
$83.5
Decommissioning trust funds (a):
               
Equity securities
 
1.6
 
282.0
 
-
 
283.6
Debt securities
 
141.1
 
65.9
 
-
 
207.0
   
$226.2
 
$347.9
 
$-
 
$574.1

(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 for additional information on the investment portfolios.


 
78

Entergy Corporation and Subsidiaries
Notes to Financial Statements


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

Entergy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts.  The NRC requires Entergy subsidiaries to maintain trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades (NYPA currently retains the decommissioning trusts and liabilities for Indian Point 3 and FitzPatrick).  The funds are invested primarily in equity securities, fixed-rate fixed-income securities, and cash and cash equivalents.

Entergy records decommissioning trust funds on the balance sheet at their fair value.  Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets.  For the nonregulated portion of River Bend, Entergy Gulf States Louisiana has recorded an offsetting amount of unrealized gains/(losses) in other deferred credits.  Decommissioning trust funds for Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades do not meet the criteria for regulatory accounting treatment.  Accordingly, unrealized gains recorded on the assets in these trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity because these assets are classified as available for sale.  Unrealized losses (where cost exceeds fair market value) on the assets in these trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings.  Generally, Entergy records realized gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities.

The securities held as of September 30, 2013 and December 31, 2012 are summarized as follows:

   
 
Fair
Value
 
Total
Unrealized
Gains
 
Total
Unrealized
Losses
   
(In Millions)
             
2013
           
Equity Securities
 
$2,888
 
$1,067
 
$1
Debt Securities
 
1,740
 
59
 
24
  Total
 
$4,628
 
$1,126
 
$25

   
 
Fair
Value
 
Total
Unrealized
Gains
 
Total
Unrealized
Losses
   
(In Millions)
             
2012
           
Equity Securities
 
$2,459
 
$662
 
$1
Debt Securities
 
1,731
 
116
 
5
  Total
 
$4,190
 
$778
 
$6

Deferred taxes on unrealized gains/(losses) are recorded in other comprehensive income for the decommissioning trusts which do not meet the criteria for regulatory accounting treatment as described above. Unrealized gains/(losses) above are reported before deferred taxes of $276 million and $211 million as of September 30, 2013 and December 31, 2012, respectively.  The amortized cost of debt securities was $1,709 million as of September 30, 2013 and $1,637 million as of December 31, 2012.  As of September 30, 2013, the debt securities have an average coupon rate of approximately 3.54%, an average duration of approximately 5.13 years, and an average maturity of approximately 7.68 years.  The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index.
 
 
79

Entergy Corporation and Subsidiaries
Notes to Financial Statements


The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2013:

   
Equity Securities
 
Debt Securities
   
 
Fair
Value
 
Gross
Unrealized
Losses
 
 
Fair
Value
 
Gross
Unrealized
Losses
   
(In Millions)
                 
Less than 12 months
 
$19
 
$1
 
$589
 
$21
More than 12 months
 
-
 
-
 
39
 
3
  Total
 
$19
 
$1
 
$628
 
$24

The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2012:

   
Equity Securities
 
Debt Securities
   
 
Fair
Value
 
Gross
Unrealized
Losses
 
 
Fair
Value
 
Gross
Unrealized
Losses
   
(In Millions)
                 
Less than 12 months
 
$37
 
$1
 
$175
 
$1
More than 12 months
 
20
 
-
 
48
 
4
  Total
 
$57
 
$1
 
$223
 
$5

The unrealized losses in excess of twelve months on equity securities above relate to Entergy’s Utility operating companies and System Energy.

The fair value of debt securities, summarized by contractual maturities, as of September 30, 2013 and December 31, 2012 are as follows:

   
2013
 
2012
   
(In Millions)
less than 1 year
 
$109
 
$53
1 year - 5 years
 
679
 
681
5 years - 10 years
 
574
 
562
10 years - 15 years
 
145
 
164
15 years - 20 years
 
59
 
61
20 years+
 
174
 
210
  Total
 
$1,740
 
$1,731

During the three months ended September 30, 2013 and 2012, proceeds from the dispositions of securities amounted to $284 million and $472 million, respectively.  During the three months ended September 30, 2013 and 2012, gross gains of $3 million and $8 million, respectively, and gross losses of $4 million and $0.2 million, respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.


 
80

Entergy Corporation and Subsidiaries
Notes to Financial Statements


During the nine months ended September 30, 2013 and 2012, proceeds from the dispositions of securities amounted to $1,064 million and $1,417 million, respectively.  During the nine months ended September 30, 2013 and 2012, gross gains of $25 million and $32 million, respectively, and gross losses of $7 million and $5 million, respectively, were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

Entergy Arkansas

Entergy Arkansas holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts.  The securities held as of September 30, 2013 and December 31, 2012 are summarized as follows:

   
 
Fair
Value
 
Total
Unrealized
Gains
 
Total
Unrealized
Losses
   
(In Millions)
2013
           
Equity Securities
 
$430.8
 
$181.7
 
$-
Debt Securities
 
239.0
 
6.3
 
4.1
Total
 
$669.8
 
$188.0
 
$4.1
             
2012
           
Equity Securities
 
$384.0
 
$116.1
 
$-
Debt Securities
 
216.6
 
14.5
 
0.2
Total
 
$600.6
 
$130.6
 
$0.2

The amortized cost of debt securities was $240 million as of September 30, 2013 and $202.3 million as of December 31, 2012.  As of September 30, 2013, the debt securities have an average coupon rate of approximately 2.83%, an average duration of approximately 5.30 years, and an average maturity of approximately 6.03 years.  The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2013:

   
Equity Securities
 
Debt Securities
   
 
Fair
Value
 
Gross
Unrealized
Losses
 
 
Fair
Value
 
Gross
Unrealized
Losses
   
(In Millions)
                 
Less than 12 months
 
$0.1
 
$-
 
$123.7
 
$3.9
More than 12 months
 
-
 
-
 
3.3
 
0.2
Total
 
$0.1
 
$-
 
$127.0
 
$4.1

The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2012:

 
81

Entergy Corporation and Subsidiaries
Notes to Financial Statements



   
Equity Securities
 
Debt Securities
   
 
Fair
Value
 
Gross
Unrealized
Losses
 
 
Fair
Value
 
Gross
Unrealized
Losses
   
(In Millions)
                 
Less than 12 months
 
$0.2
 
$-
 
$24.4
 
$0.2
More than 12 months
 
-
 
-
 
1.0
 
-
Total
 
$0.2
 
$-
 
$25.4
 
$0.2

The fair value of debt securities, summarized by contractual maturities, as of September 30, 2013 and December 31, 2012 are as follows:

   
2013
 
2012
   
(In Millions)
         
less than 1 year
 
$8.2
 
$8.8
1 year - 5 years
 
100.5
 
98.6
5 years - 10 years
 
122.3
 
93.1
10 years - 15 years
 
3.3
 
5.1
15 years - 20 years
 
0.9
 
-
20 years+
 
3.8
 
11.0
Total
 
$239.0
 
$216.6

During the three months ended September 30, 2013 and 2012, proceeds from the dispositions of securities amounted to $30.3 million and $15 million, respectively.  During the three months ended September 30, 2013 and 2012, gross gains of $0.6 million and $0.1 million, respectively, and gross losses of $0.1 million and $0.01 million, respectively were reclassified out of other regulatory liabilities/assets into earnings.

During the nine months ended September 30, 2013 and 2012, proceeds from the dispositions of securities amounted to $173.4 million and $103.4 million, respectively.  During the nine months ended September 30, 2013 and 2012, gross gains of $9.3 million and $2.8 million, respectively, and gross losses of $0.2 million and $0.05 million, respectively were reclassified out of other regulatory liabilities/assets into earnings.

Entergy Gulf States Louisiana

Entergy Gulf States Louisiana holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts.  The securities held as of September 30, 2013 and December 31, 2012 are summarized as follows:

   
 
Fair
Value
 
Total
Unrealized
Gains
 
Total
Unrealized
Losses
   
(In Millions)
2013
           
Equity Securities
 
$347.2
 
$118.0
 
$-
Debt Securities
 
190.4
 
8.7
 
2.6
Total
 
$537.6
 
$126.7
 
$2.6
             
2012
           
Equity Securities
 
$288.5
 
$69.8
 
$-
Debt Securities
 
188.9
 
15.8
 
0.1
Total
 
$477.4
 
$85.6
 
$0.1
             
 
 
82

Entergy Corporation and Subsidiaries
Notes to Financial Statements



The amortized cost of debt securities was $182.5 million as of September 30, 2013 and $174.1 million as of December 31, 2012.  As of September 30, 2013, the debt securities have an average coupon rate of approximately 4.58%, an average duration of approximately 5.46 years, and an average maturity of approximately 8.10 years.  The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2013:

   
Equity Securities
 
Debt Securities
   
 
Fair
Value
 
Gross
Unrealized
Losses
 
 
Fair
Value
 
Gross
Unrealized
Losses
   
(In Millions)
                 
Less than 12 months
 
$0.4
 
$-
 
$60.0
 
$2.6
More than 12 months
 
-
 
-
 
-
 
-
  Total
 
$0.4
 
$-
 
$60.0
 
$2.6

The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2012:

   
Equity Securities
 
Debt Securities
   
 
Fair
Value
 
Gross
Unrealized
Losses
 
 
Fair
Value
 
Gross
Unrealized
Losses
   
(In Millions)
                 
Less than 12 months
 
$1.2
 
$-
 
$9.1
 
$0.1
More than 12 months
 
1.0
 
-
 
-
 
-
  Total
 
$2.2
 
$-
 
$9.1
 
$0.1

The fair value of debt securities, summarized by contractual maturities, as of September 30, 2013 and December 31, 2012 are as follows:

   
2013
 
2012
   
(In Millions)
         
less than 1 year
 
$8.0
 
$8.0
1 year - 5 years
 
41.7
 
43.5
5 years - 10 years
 
71.5
 
63.5
10 years - 15 years
 
52.8
 
55.8
15 years - 20 years
 
6.5
 
8.5
20 years+
 
9.9
 
9.6
  Total
 
$190.4
 
$188.9
 
 
83

Entergy Corporation and Subsidiaries
Notes to Financial Statements


During the three months ended September 30, 2013 and 2012, proceeds from the dispositions of securities amounted to $19.5 million and $35.9 million, respectively.  During the three months ended September 30, 2013 and 2012, gross gains of $0.3 million and $3.9 million, respectively, and gross losses of $0.02 million and $0.7 thousand, respectively, were reclassified out of other regulatory liabilities/assets into earnings.
 
During the nine months ended September 30, 2013 and 2012, proceeds from the dispositions of securities amounted to $66.2 million and $96.7 million, respectively.  During the nine months ended September 30, 2013 and 2012, gross gains of $6.6 million and $6.4 million, respectively, and gross losses of $0.03 million and $0.03 million, respectively, were reclassified out of other regulatory liabilities/assets into earnings.

Entergy Louisiana

Entergy Louisiana holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts.  The securities held as of September 30, 2013 and December 31, 2012 are summarized as follows:

   
 
Fair
Value
 
Total
Unrealized
Gains
 
Total
Unrealized
Losses
   
(In Millions)
2013
           
Equity Securities
 
$214.7
 
$82.5
 
$-
Debt Securities
 
110.7
 
5.6
 
1.5
Total
 
$325.4
 
$88.1
 
$1.5
             
2012
           
Equity Securities
 
$175.5
 
$48.9
 
$0.1
Debt Securities
 
111.9
 
9.4
 
0.1
Total
 
$287.4
 
$58.3
 
$0.2

The amortized cost of debt securities was $106.8 million as of September 30, 2013 and $102.6 million as of December 31, 2012.  As of September 30, 2013, the debt securities have an average coupon rate of approximately 3.42%, an average duration of approximately 4.91 years, and an average maturity of approximately 8.53 years.  The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2013:

   
Equity Securities
 
Debt Securities
   
 
Fair
Value
 
Gross
Unrealized
Losses
 
 
Fair
Value
 
Gross
Unrealized
Losses
   
(In Millions)
                 
Less than 12 months
 
$0.1
 
$-
 
$29.0
 
$1.4
More than 12 months
 
-
 
-
 
0.6
 
0.1
  Total
 
$0.1
 
$-
 
$29.6
 
$1.5


 
84

Entergy Corporation and Subsidiaries
Notes to Financial Statements


The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2012:

   
Equity Securities
 
Debt Securities
   
 
Fair
Value
 
Gross
Unrealized
Losses
 
 
Fair
Value
 
Gross
Unrealized
Losses
   
(In Millions)
                 
Less than 12 months
 
$0.7
 
$-
 
$3.4
 
$-
More than 12 months
 
5.6
 
0.1
 
0.5
 
0.1
  Total
 
$6.3
 
$0.1
 
$3.9
 
$0.1

The fair value of debt securities, summarized by contractual maturities, as of September 30, 2013 and December 31, 2012 are as follows:

   
2013
 
2012
   
(In Millions)
         
less than 1 year
 
$14.4
 
$1.9
1 year - 5 years
 
32.0
 
42.3
5 years - 10 years
 
35.6
 
24.9
10 years - 15 years
 
6.5
 
18.8
15 years - 20 years
 
4.5
 
1.7
20 years+
 
17.7
 
22.3
  Total
 
$110.7
 
$111.9

During the three months ended September 30, 2013 and 2012, proceeds from the dispositions of securities amounted to $2.7 million and $9.5 million, respectively.  During the three months ended September 30, 2013 and 2012, gross gains of $0.01 million and $0.1 million, respectively, and gross losses of $0.01 million and $0.5 thousand, respectively, were reclassified out of other regulatory liabilities/assets into earnings.

During the nine months ended September 30, 2013 and 2012, proceeds from the dispositions of securities amounted to $12.2 million and $19.8 million, respectively.  During the nine months ended September 30, 2013 and 2012, gross gains of $0.06 million and $0.2 million, respectively, and gross losses of $0.03 million and $0.03 million, respectively, were reclassified out of other regulatory liabilities/assets into earnings.


 
85

Entergy Corporation and Subsidiaries
Notes to Financial Statements


System Energy

System Energy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts.  The securities held as of September 30, 2013 and December 31, 2012 are summarized as follows:

   
 
Fair
Value
 
Total
Unrealized
Gains
 
Total
Unrealized
Losses
   
(In Millions)
2013
           
Equity Securities
 
$343.8
 
$117.9
 
$-
Debt Securities
 
219.6
 
4.6
 
1.2
Total
 
$563.4
 
$122.5
 
$1.2
             
2012
           
Equity Securities
 
$283.6
 
$63.6
 
$0.2
Debt Securities
 
207.0
 
9.3
 
0.1
Total
 
$490.6
 
$72.9
 
$0.3

The amortized cost of debt securities was $216.5 million as of September 30, 2013 and $197.8 million as of December 31, 2012.  As of September 30, 2013, the debt securities have an average coupon rate of approximately 2.57%, an average duration of approximately 4.47 years, and an average maturity of approximately 5.97 years.  The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2013:

   
Equity Securities
 
Debt Securities
   
 
Fair
Value
 
Gross
Unrealized
Losses
 
 
Fair
Value
 
Gross
Unrealized
Losses
   
(In Millions)
                 
Less than 12 months
 
$0.2
 
$-
 
$52.9
 
$1.2
More than 12 months
 
-
 
-
 
-
 
-
  Total
 
$0.2
 
$-
 
$52.9
 
$1.2

The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by investment type and length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2012:

   
Equity Securities
 
Debt Securities
   
 
Fair
Value
 
Gross
Unrealized
Losses
 
 
Fair
Value
 
Gross
Unrealized
Losses
   
(In Millions)
                 
Less than 12 months
 
$1.4
 
$-
 
$15.5
 
$0.1
More than 12 months
 
13.0
 
0.2
 
-
 
-
  Total
 
$14.4
 
$0.2
 
$15.5
 
$0.1
 
 
86

Entergy Corporation and Subsidiaries
Notes to Financial Statements



The fair value of debt securities, summarized by contractual maturities, as of September 30, 2013 and December 31, 2012 are as follows:

   
2013
 
2012
   
(In Millions)
         
less than 1 year
 
$10.4
 
$1.3
1 year - 5 years
 
132.4
 
128.7
5 years - 10 years
 
51.0
 
53.9
10 years - 15 years
 
6.3
 
2.3
15 years - 20 years
 
2.0
 
1.4
20 years+
 
17.5
 
19.4
  Total
 
$219.6
 
$207.0

During the three months ended September 30, 2013 and 2012, proceeds from the dispositions of securities amounted to $53.4 million and $91.8 million, respectively.  During the three months ended September 30, 2013 and 2012, gross gains of $0.1 million and $0.5 million, respectively, and gross losses of $0.8 million and $0.05 million, respectively, were reclassified out of other regulatory liabilities/assets into earnings.

During the nine months ended September 30, 2013 and 2012, proceeds from the dispositions of securities amounted to $144.6 million and $315.0 million, respectively.  During the nine months ended September 30, 2013 and 2012, gross gains of $0.9 million and $3.5 million, respectively, and gross losses of $1.2 million and $0.2 million, respectively, were reclassified out of other regulatory liabilities/assets into earnings.

Other-than-temporary impairments and unrealized gains and losses

Entergy, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy evaluate unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred.  The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs.  Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss).  Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three and nine months ended September 30, 2013 and 2012.  The assessment of whether an investment in an equity security has suffered an other-than-temporary impairment continues to be based on a number of factors including, first, whether Entergy has the ability and intent to hold the investment to recover its value, the duration and severity of any losses, and, then, whether it is expected that the investment will recover its value within a reasonable period of time.  Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.  Entergy did not record material charges to other income in the three and nine months ended September 30, 2013 and 2012, respectively, resulting from the recognition of the other-than-temporary impairment of certain equity securities held in its decommissioning trust funds.


 
87

Entergy Corporation and Subsidiaries
Notes to Financial Statements


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

See Income Tax Litigation, 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 proceedings, income tax audits, and other income tax matters involving Entergy.  Following are updates to that disclosure.

In March 2013, Entergy Louisiana distributed to its parent, Entergy Louisiana Holdings, Inc., Louisiana income tax credits of $20.6 million which resulted in a decrease in Entergy Louisiana’s member’s equity account.

As discussed in the Form 10-K, oral argument in PPL’s U.K. Windfall Tax case at the United States Supreme Court was heard in February 2013.  On May 20, 2013, the Supreme Court issued a unanimous decision in PPL’s favor, holding that the U.K. Windfall Tax is a creditable tax for U.S. federal income tax purposes.  On May 28, 2013, the Supreme Court denied the petition for certiorari filed by the Commissioner of Internal Revenue in Entergy’s U.K. Windfall Tax case, allowing the decision in Entergy’s favor from the United States Court of Appeals for the Fifth Circuit to become final.

In the third quarter 2013, the IRS issued its Revenue Agent’s Report (RAR) for the tax years 2008-2009.  As a result of the issuance of this RAR, Entergy and the IRS resolved all of the 2008-2009 issues described in the Form 10-K except for the Applications for Change in Accounting Method (the 2009 CAM).  Entergy disagrees with the IRS’s disallowance of the 2009 CAM and filed a protest with the IRS Appeals Division on October 24, 2013.  The issuance of the RAR by the IRS effectively settles all other issues which resulted in an adjustment to the provision for uncertain tax positions.  Entergy also negotiated favorable interest settlements with state taxing authorities which allowed for an adjustment to the provision for uncertain tax positions.

Entergy also reduced a valuation allowance that had been provided on a state net operating loss carryover due to the prospective utilization of such loss carryover.

In September 2013 the IRS issued final regulations that provide guidance on the deductibility and capitalization of costs incurred associated with tangible property.   Although Entergy continues to analyze these regulations, which contain numerous complex provisions, Entergy currently estimates that the effect of the regulations would result in a $348 million reduction of Entergy’s repair and maintenance tax deduction, including decreases of $114 million for Entergy Arkansas, $34 million for Entergy Gulf States Louisiana, $22 million for Entergy Louisiana, $43 million for Entergy Mississippi, $137 million for Entergy Texas, and an increase of $2 million for Entergy New Orleans.


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

Construction Expenditures in Accounts Payable

Construction expenditures included in accounts payable at September 30, 2013 are $91.5 million for Entergy, $25.6 million for Entergy Arkansas, $17.7 million for Entergy Gulf States Louisiana, $12.4 million for Entergy Louisiana, $0.8 million for Entergy Mississippi, $1.4 million for Entergy New Orleans, $4.7 million for Entergy Texas, and $5.2 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2012 are $267 million for Entergy, $56.3 million for Entergy Arkansas, $9.7 million for Entergy Gulf States Louisiana, $110.4 million for Entergy Louisiana, $4.8 million for Entergy Mississippi, $1.9 million for Entergy New Orleans, $8.6 million for Entergy Texas, and $13.5 million for System Energy.


 
88

Entergy Corporation and Subsidiaries
Notes to Financial Statements


Impairment of Long-Lived Assets

See “Impairment of Long-Lived Assets” in Note 1 to the financial statements in the Form 10-K for a discussion of the periodic reviews that Entergy performs whenever events or changes in circumstances indicate that the recoverability of long-lived assets is uncertain.  Following are updates to that discussion regarding the Vermont Yankee nuclear power plant.

First, as discussed in the Form 10-K, Entergy was seeking a Certificate of Public Good from the Vermont Public Service Board (VPSB) for operation of Vermont Yankee until March 2032.  In June 2013 the VPSB completed hearings on that petition and established a schedule providing for proposals for decision and initial briefs to be filed in August 2013 and reply briefs to be filed in September 2013.  After Entergy announced its plan to close Vermont Yankee in the fourth quarter of 2014, as discussed below, Entergy amended its Certificate of Public Good request to seek authorization to operate Vermont Yankee only through 2014.  The VPSB thereafter postponed the date for reply briefs to be filed until October 2013 and invited comments on the reply briefs to be filed in November 2013.  Second, as discussed in the Form 10-K, the New England Coalition in December 2012 filed a complaint in the Vermont Supreme Court seeking an order to shut down Vermont Yankee while its Certificate of Public Good application is pending, and Entergy moved to dismiss that complaint.  On March 25, 2013, the Vermont Supreme Court granted Entergy’s motion and dismissed the complaint.  Third, as discussed in the Form 10-K, Entergy appealed a January 2013 order of the VPSB that made ripe for appeal two earlier orders in which the VPSB had found that the state’s timely renewal law, 3 V.S.A. § 814(b), did not apply to certain conditions in the orders issued by the VPSB in 2002 and 2006 precluding Vermont Yankee’s operation after March 21, 2012.  Briefing of this appeal has been completed.  After Entergy announced its plan to close Vermont Yankee in 2014, the Vermont Supreme Court placed the appeal on waiting status until after the VPSB has ruled on Vermont Yankee’s pending petition for a Certificate of Public Good.  Fourth, as discussed in the Form 10-K, in February 2013 the VPSB issued a notice allowing comments to be filed regarding Vermont Yankee’s petition for a Certificate of Public Good to install a diesel generator to enable it to comply with the NRC’s station blackout requirements.  On June 6, 2013, the VPSB issued a Certificate of Public Good for the diesel generator.  The generator was installed and put into service before the September 1, 2013 deadline for compliance with these NRC requirements.  Fifth, on August 14, 2013, the U.S. Court of Appeals for the Second Circuit affirmed the January 2012 District Court decision that the Atomic Energy Act preempts Vermont’s laws requiring the Legislature’s authorization for Vermont Yankee to operate after March 21, 2012 and to store spent nuclear fuel from some operation and also affirmed the District Court’s permanent injunction prohibiting enforcement of these Vermont laws.  The Second Circuit reversed the District Court’s decision that Vermont’s efforts to condition a CPG upon the existence of a below wholesale market power sales agreement violated the Dormant Commerce Clause of the U.S. Constitution, and affirmed the District Court’s decision that such efforts were not preempted by the Federal Power Act, on the ground that these claims were not yet ripe.

Impairments of Vermont Yankee

See the Form 10-K for a discussion of the impairment charge recorded for the Vermont Yankee plant in the first quarter 2012.

On August 27, 2013, Entergy announced its plan to close and decommission Vermont Yankee.  Vermont Yankee is expected to cease power production in the fourth quarter 2014 after its current fuel cycle.  This decision was approved by the Board in August 2013.  The decision to shut down the plant was primarily due to sustained low natural gas and wholesale energy prices, the high cost structure of the plant, and lack of a market structure that adequately compensates merchant nuclear plants for their environmental and fuel diversity benefits in the region in which the plant operates.
 
 
89

Entergy Corporation and Subsidiaries
Notes to Financial Statements

As a result of the decision to shut down the plant, Entergy recognized non-cash impairment and other related charges of $291.5 million ($183.7 million after-tax) during the third quarter 2013 to write down the carrying value of Vermont Yankee and related assets to their fair values.  Entergy performed a fair value analysis based on the income approach, a discounted cash flow method, to determine the amount of impairment.  The estimated fair value of the plant and related assets was $62 million, while the carrying value was $349 million.  The carrying value of $349 million reflects the effect of a $58 million increase in Vermont Yankee’s estimated decommissioning cost liability and the related asset retirement cost asset.  The increase in the estimated decommissioning cost liability resulted from the change in expectation regarding the timing of decommissioning cash flows due to the decision to cease operations.  The impairment and other related charges are recorded as a separate line item in Entergy’s consolidated statements of income for the three and nine months ended September 30, 2013 and is included within the results of the Entergy Wholesale Commodities segment.

The estimate of fair value was based on the price that Entergy would expect to receive in a hypothetical sale of the Vermont Yankee plant and related assets to a market participant.  In order to determine this price, Entergy used significant observable inputs, including quoted forward power and gas prices, where available.  Significant unobservable inputs, such as projected long-term pre-tax operating margins (cash basis), and estimated weighted average costs of capital were also used in the estimation of fair value.  In addition, Entergy made certain assumptions regarding future tax deductions associated with the plant and related assets.  Based on the use of significant unobservable inputs, the fair value measurement for the entirety of the asset group, and for each type of asset within the asset group, is classified as Level 3 in the fair value hierarchy discussed in Note 8 to the financial statements.

The following table sets forth a description of significant unobservable inputs used in the valuation of the Vermont Yankee plant and related assets:

Significant Unobservable Input
 
Amount
     
Weighted average cost of capital
 
7.5%
Long-term pre-tax operating margin (cash basis)
 
7.0%

Entergy’s Accounting Policy group, which reports to the Chief Accounting Officer, was primarily responsible for determining the valuation of the Vermont Yankee plant and related assets, in consultation with external advisors.  Entergy’s Accounting Policy group obtained and reviewed information from other Entergy departments with expertise on the various inputs and assumptions that were necessary to calculate the fair value of the asset group.

In addition to the impairment charge and depreciation of the remaining plant balance by the end of 2014, Entergy expects to record additional charges through the end of 2014 totaling approximately $55 million to $60 million related to severance and employee retention costs relating to the shutdown of Vermont Yankee.


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

See Note 18 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 facility and commercial paper borrowings and long-term debt.

Entergy Louisiana and System Energy are each considered to hold a variable interest in the lessors from which they lease, respectively, undivided interests representing approximately 9.3% of the Waterford 3 and 11.5% of the Grand Gulf nuclear plants.  Entergy Louisiana and System Energy are the lessees under these arrangements, which are described in more detail in Note 10 to the financial statements in the Form 10-K.  Entergy Louisiana made payments on its lease, including interest, of $7.8 million and $12.3 million in the three months ended September 30, 2013 and 2012, respectively. Entergy Louisiana made payments on its lease, including interest, of $26.3 million and $39.1 million in the nine months ended September 30, 2013 and 2012, respectively.  System Energy made payments on its lease, including interest, of $3.7 million and $1.8 million in the three months ended September 30, 2013 and 2012, respectively. System Energy made payments on its lease, including interest, of $50.5 million and $50.0 million in the nine months ended September 30, 2013 and 2012, respectively.



 
90

Entergy Corporation and Subsidiaries
Notes to Financial Statements


NOTE 13.  ASSET RETIREMENT OBLIGATIONS  (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations.  Following is an update to that discussion.

In the first quarter 2013, Entergy Wholesale Commodities recorded a revision to its estimated decommissioning cost liability for a nuclear site as a result of a revised decommissioning cost study.  The revised estimate resulted in a $46.6 million reduction in the decommissioning cost liability, along with a corresponding reduction in the related asset retirement cost asset.

In the third quarter 2013, Entergy Wholesale Commodities recorded a revision to its estimated decommissioning cost liability for Vermont Yankee as a result of a revised decommissioning cost study. The revised estimate resulted in a $58 million increase in the decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset. The increase in the estimated decommissioning cost liability resulted from the change in expectation regarding the timing of decommissioning cash flows due to the decision to cease operations of the plant.  See Note 11 to the financial statements herein for further discussion of the Vermont Yankee plant.

Assuming the end of Vermont Yankee operations in the fourth quarter 2014, the amount required to meet the NRC minimum for decommissioning financial assurance for license termination is $566 million.  The Vermont Yankee decommissioning trust had a balance of approximately $584 million as of September 30, 2013, excluding the $40 million guarantee by Entergy Corporation to satisfy NRC requirements following the 2009 review of financial assurance levels.  Filings with the NRC for planned shutdown activities will determine whether any other financial assurance may be required and will specifically address funding for spent fuel management, which will be required until the federal government takes possession of the fuel and removes it from the site, per its current obligations.
__________________________________

In the opinion of the management of Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, 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 the interim periods presented.  The business of the Registrant Subsidiaries is subject to seasonal fluctuations, however, with the peak periods occurring during the third quarter.  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 4. Controls and Procedures

Disclosure Controls and Procedures

As of September 30, 2013, evaluations were performed under the supervision and with the participation of Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy (individually “Registrant” and collectively the “Registrants”) management, including their respective Principal Executive Officers (PEO) and Principal Financial Officers (PFO).  The evaluations assessed the effectiveness of the Registrants’ disclosure controls and procedures.  Based on the evaluations, each PEO and PFO has concluded that, as to the Registrant or Registrants for which they serve as PEO or PFO, the Registrant’s or Registrants’ disclosure controls and procedures are effective to ensure that information required to be disclosed by each Registrant in reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in Securities and Exchange Commission rules and forms; and that the Registrant’s or Registrants’ disclosure controls and procedures are also effective in reasonably assuring that such information is accumulated and communicated to the Registrant’s or Registrants’ management, including their respective PEOs and PFOs, as appropriate to allow timely decisions regarding required disclosure.

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 September 30, 2013 and found no change that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.


ENTERGY ARKANSAS, INC. AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS


Plan to Spin Off the Utility’s Transmission Business

See thePlan to Spin Off the Utility’s Transmission Businesssection of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K and herein for a discussion of Entergy’s plan to spin off its transmission business and merge it with a newly formed subsidiary of ITC Holdings Corp., including the planned retirement of debt and preferred securities.

Results of Operations

Net Income

Third Quarter 2013 Compared to Third Quarter 2012

Net income remained relatively unchanged.  Higher net revenue and lower taxes other than income taxes were offset by higher other operation and maintenance expenses, higher depreciation and amortization expenses, and higher interest expense.

Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Net income decreased $4.4 million primarily due to higher other operation and maintenance expenses, a higher effective income tax rate, higher interest expense, and higher depreciation and amortization expenses, partially offset by higher net revenue and higher other income.
 
 Net Revenue

Third Quarter 2013 Compared to Third Quarter 2012

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory credits.  Following is an analysis of the change in net revenue comparing the third quarter 2013 to the third quarter 2012:

   
Amount
   
(In Millions)
     
2012 net revenue
 
$397.4 
Retail electric price
 
13.8 
ANO decommissioning trust
 
3.2 
Volume/weather
 
(6.7)
Other
 
0.1 
2013 net revenue
 
$407.8 

The retail electric price variance is primarily due to:

·  
an increase in the capacity acquisition rider, as approved by the APSC, effective with the first billing cycle of December 2012, relating to the Hot Spring plant acquisition.  The net income effect of the Hot Spring plant cost recovery is limited to a portion representing an allowed return on equity on the net plant investment with the remainder offset by the Hot Spring plant costs in other operation and maintenance expenses, depreciation expenses, and taxes other than income taxes; and

 
93

Entergy Arkansas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis



·  
an increase in the energy efficiency rider, as approved by the APSC, effective July 2013.  Energy efficiency revenues are offset by costs included in other operation and maintenance expenses and have no effect on net income.

The ANO decommissioning trust variance is primarily due to higher regulatory credits resulting from a decrease in interest earned on decommissioning trust fund investments. There is no effect on net income as this interest is reflected in other income.

The volume/weather variance is primarily due to the effect of less favorable weather on residential and commercial sales, partially offset by an increase in sales volume in the unbilled sales period.

Gross operating revenues and fuel and purchased power expenses

Gross operating revenues decreased primarily due to a decrease of $37 million in fuel cost recovery revenues as a result of lower fuel rates and the decrease related to volume/weather, as discussed above.

The decrease was partially offset by:

·  
an increase of $16.8 million in gross wholesale revenues primarily due to increased sales to affiliated customers and higher prices;
·  
an increase of $9.6 million due to the increase in the capacity acquisition rider, as discussed above; and
·  
an increase of $4.7 million in rider revenues primarily due to an increase in the Grand Gulf rate effective January 2013.

Fuel and purchased power expenses decreased primarily due to a decrease in the recovery from customers of deferred fuel costs due to lower fuel rates.  This decrease was offset by increased gas-fired generation due to an increase in demand as a result of the ANO extended outage and an increase in the average market prices of natural gas.

Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory credits.  Following is an analysis of the change in net revenue comparing the nine months ended September 30, 2013 to the nine months ended September 30, 2012:

   
Amount
   
(In Millions)
     
2012 net revenue
 
$987.5 
Retail electric price
 
36.6 
MISO deferral
 
11.1 
Net wholesale revenue
 
5.9 
Volume/weather
 
(15.3)
Other
 
(3.6)
2013 net revenue
 
$1,022.2 

The retail electric price variance is primarily due to:

·  
an increase in the capacity acquisition rider, as approved by the APSC, effective with the first billing cycle of December 2012, relating to the Hot Spring plant acquisition.  The net income effect of the Hot Spring plant cost recovery is limited to a portion representing an allowed return on equity on the net plant investment with the remainder offset by the Hot Spring plant costs in other operation and maintenance expenses, depreciation expenses, and taxes other than income taxes; and
 
 
94

Entergy Arkansas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis


 
·  
an increase in the energy efficiency rider, as approved by the APSC, effective July 2013 and July 2012.  Energy efficiency revenues are offset by costs included in other operation and maintenance expenses and have no effect on net income.

The MISO deferral variance is due to the deferral in April 2013, as approved by the APSC, of costs incurred since March 2010 related to the transition and implementation of joining the MISO RTO.

The net wholesale variance is primarily due to higher margins on co-owner contracts.

The volume/weather variance is primarily due to a decrease of 481 GWh, or 3%, in billed electricity, including the effect of less favorable weather, as compared to the prior year, on residential and commercial sales.

Gross operating revenues, fuel and purchased power expenses, and other regulatory credits

Gross operating revenues increased primarily due to:

·  
an increase of $42.7 million in gross wholesale revenues primarily due to increased sales to affiliated customers and higher prices;
·  
the June 2012 AmerenUE refund of $30.6 million, including interest, in rough production cost equalization payments collected from AmerenUE.  Entergy Arkansas had previously recorded a regulatory provision for the potential refund to AmerenUE.  The result of the refund in 2012 was a decrease in gross revenues with an offsetting increase in other regulatory credits.  See Note 2 to the financial statements in the Form 10-K for a discussion of the FERC order in the System Agreement production cost equalization proceedings;
·  
an increase of $22.9 million due to the increase in the capacity acquisition rider, as discussed above;
·  
an increase of $17 million in rider revenues primarily due to an increase in the Grand Gulf rate effective January 2013;
·  
an increase of $14.6 million in rider revenues due to increases in the energy efficiency rider effective July 2013 and July 2012, as discussed above; and
·  
an increase of $11.3 million in rider revenues related to higher System Agreement production cost equalization payments.  These revenues are offset in deferred fuel expenses.  See Note 2 to the financial statements herein and in the Form 10-K for a discussion of the FERC orders in the System Agreement production cost equalization proceedings.

The increase was partially offset by a decrease of $68.3 million in fuel cost recovery revenues as a result of lower fuel rates, and the decrease related to volume/weather, as discussed above.

Fuel and purchased power expenses increased primarily due to:

·  
increased purchased power costs and gas-fired generation due to an increase in demand as a result of the ANO extended outage as well as increases in the average market prices of purchased power and natural gas; and
·  
higher costs related to System Agreement production cost equalization payments, as discussed above.

The increase was partially offset by a decrease in the recovery from customers of deferred fuel costs.

Other regulatory credits decreased primarily due to the June 2012 refund to AmerenUE, as discussed above, and higher deferred gains in 2013 on the ANO 1 decommissioning trust fund investments.  These decreases were partially offset by the deferral of MISO costs in April 2013, as discussed above.

 
95

Entergy Arkansas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis


Other Income Statement Variances

Third Quarter 2013 Compared to Third Quarter 2012

Other operation and maintenance expenses increased primarily due to:

·  
an increase of $3.5 million in compensation and benefits costs primarily due to a decrease in the discount rates used to determine net periodic pension and other postretirement benefit costs and a settlement charge, recognized in September 2013, related to the payment of lump sum benefits out of the non-qualified pension plan.  See "MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates" in the Form 10-K and Note 6 to the financial statements herein for further discussion of benefits costs;
·  
an increase of $2.5 million in energy efficiency costs.  These costs are recovered through the energy efficiency rider and have no effect on net income;
·  
an increase of $2.1 million in distribution contract work primarily due to vegetation maintenance; and
·  
an increase of $2.1 million in fossil-fueled generation expenses primarily due to the addition of the Hot Spring plant in November 2012, partially offset by higher plant outage costs in 2012 due to a greater scope of work.

These increases were partially offset by a decrease of $2.8 million in nuclear generation costs primarily due to lower labor and contract costs.

Depreciation and amortization expenses increased primarily due to the acquisition of the Hot Spring plant in November 2012.

Interest expense increased primarily due to the issuance of $200 million of 4.90% Series first mortgage bonds in December 2012, the issuance of $250 million of 3.05% Series first mortgage bonds in May 2013, and the issuance of $125 million of 4.75% Series first mortgage bonds in June 2013.  This increase was partially offset by the retirement, at maturity, of $300 million of 5.40% Series first mortgage bonds in August 2013.

Taxes other than income taxes decreased primarily due to a decrease in local franchise tax resulting from lower commercial and residential revenues as compared to the same period in 2012.
 
Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Other operation and maintenance expenses increased primarily due to:

·  
an increase of $12 million in energy efficiency costs.  These costs are recovered through the energy efficiency rider and have no effect on net income;
·  
an increase of $11 million resulting from costs related to the generator stator incident at ANO, including an offset for expected insurance proceeds.  See “ANO Damage and Outage” below for further discussion of the incident;
·  
an increase of $10.8 million in fossil-fueled generation expenses primarily due to the addition of the Hot Spring plant in November 2012; and
·  
an increase of $8.7 million in compensation and benefits costs primarily due to a decrease in the discount rates used to determine net periodic pension and other postretirement benefit costs and a settlement charge, recognized in September 2013, related to the payment of lump sum benefits out of the non-qualified pension plan.  See "MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates" in the Form 10-K and Note 6 to the financial statements herein for further discussion of benefits costs.


 
96

Entergy Arkansas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis


The increase was partially offset by:

·  
a decrease of $3.4 million due to costs incurred in 2012 related to the transition and implementation of joining the MISO RTO.  In April 2013, Entergy Arkansas began deferring these costs as approved by the APSC; and
·  
the effects of recording the final court decision in the Entergy Arkansas lawsuit against the U.S. Department of Energy related to spent nuclear fuel disposal.  The damages awarded include the reimbursement of approximately $3.2 million of spent nuclear fuel storage costs previously recorded as other operation and maintenance expense.  The spent nuclear fuel disposal litigation is discussed in more detail in Part II, Item 5, “Spent Nuclear Fuel.”

Depreciation and amortization expenses increased primarily due to the acquisition of the Hot Spring plant in November 2012, partially offset by the effects of recording the final court decision in the Entergy Arkansas lawsuit against the U.S. Department of Energy related to spent nuclear fuel disposal.  The damages awarded include the reimbursement of approximately $3.6 million of spent nuclear fuel storage costs previously recorded as depreciation expense.  The spent nuclear fuel disposal litigation is discussed in more detail in Part II, Item 5, and “Spent Nuclear Fuel.”

Interest expense increased primarily due to the issuance of $200 million of 4.90% Series first mortgage bonds in December 2012.

Other income increased primarily due to higher realized gains in 2013 on the ANO 1 decommissioning trust fund investments.  There is no effect on net income as these investment gains are offset by a corresponding amount of regulatory charges.

Income Taxes

The effective income tax rate was 40.6% for the third quarter 2013 and 42.3% for the nine months ended September 30, 2013.  The differences in the effective income tax rates for the third quarter 2013 and the nine months ended September 30, 2013 versus the federal statutory rate of 35% were due to state income taxes, certain book and tax differences related to utility plant items, and the provision for uncertain tax positions, partially offset by book and tax differences related to the allowance for equity funds used during construction.

 The effective income tax rate was 40.4% for the third quarter 2012 and 39.5% for the nine months ended September 30, 2012. The difference in the effective income tax rate for the third quarter 2012 versus the federal statutory rate of 35% was due to state income taxes and certain book and tax differences related to utility plant items. The difference in the effective income tax rate for the nine months ended September 30, 2012 versus the federal statutory rate of 35% was due to state income taxes and certain book and tax differences related to utility plant items, partially offset by the provision for uncertain tax positions.

ANO Damage and Outage

On March 31, 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator stator out of the turbine building.  The collapse resulted in the death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the ANO turbine building.  The turbine building serves both ANO 1 and 2 and is a non-radiological area of the plant.  ANO 2 reconnected to the grid on April 28, 2013 and ANO 1 reconnected to the grid on August 7, 2013.  The total cost of assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment is currently estimated to be approximately $100 million.  In addition, Entergy Arkansas incurred replacement power costs for ANO 2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage extended beyond the originally-planned duration of the refueling outage.  Each of the Utility operating companies has recovery mechanisms in place designed to recover its prudently-incurred fuel and purchased power costs.
 
 
97

Entergy Arkansas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis


Entergy Arkansas is assessing its options for recovering damages that resulted from the stator drop, including its insurance coverage and legal action.  Entergy is a member of Nuclear Electric Insurance Limited (NEIL), a mutual insurance company that provides property damage coverage to the members’ nuclear generating plants, including ANO.  NEIL has notified Entergy that it believes that a $50 million course of construction sublimit applies to any loss associated with the lifting apparatus failure and stator drop at ANO.  Entergy has responded that it disagrees with NEIL's position and is evaluating its options for enforcing its rights under the policy.  On July 12, 2013, Entergy Arkansas filed a complaint in the Circuit Court in Pope County, Arkansas against the owner of the heavy-lifting apparatus that collapsed, an engineering firm, a general contractor, and certain individuals asserting claims of breach of contract, negligence, and gross negligence in connection with their responsibility for the stator drop.

In the second quarter 2013, Entergy Arkansas recorded an insurance receivable of $50 million based on the minimum amount that it expects to receive from NEIL.  This $50 million receivable offset approximately $35 million of capital spending, $13 million of operation and maintenance expense, and $2 million of incremental deferred refueling outage costs incurred for the recovery through September 30, 2013.  As of September 30, 2013, Entergy Arkansas has incurred approximately $33 million in capital spending, $11 million in operation and maintenance expense, and $1 million in incremental deferred refueling outage costs in excess of its recorded insurance receivable.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2013 and 2012 were as follows:

   
2013
 
2012
   
(In Thousands)
         
Cash and cash equivalents at beginning of period
 
$34,533 
 
$22,599 
         
Cash flow provided by (used in):
       
 
Operating activities
 
201,757 
 
337,920 
 
Investing activities
 
(435,244)
 
(324,656)
 
Financing activities
 
244,017 
 
6,759 
Net increase in cash and cash equivalents
 
10,530 
 
20,023 
         
Cash and cash equivalents at end of period
 
$45,063 
 
$42,622 

Operating Activities

           Net cash flow provided by operating activities decreased $136.2 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to:

·  
income tax payments of $211.4 million in 2013 compared to income tax refunds of $6.9 million in 2012.  Entergy Arkansas had income tax payments in 2013 in accordance with the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement.  The income tax payments in 2013 resulted primarily from the reversal of temporary differences for which Entergy Arkansas had previously claimed a tax deduction;
·  
approximately $27 million in spending related to the generator stator incident at ANO, as discussed above; and
·  
$22.6 million in storm restoration spending in 2013 resulting from the December 2012 winter storm which caused significant damage to Entergy Arkansas’s distribution lines, equipment, poles and other facilities.


 
98

Entergy Arkansas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis


These decreases were offset by:

·  
proceeds of $38 million received in 2013 from the U.S. Department of Energy resulting from litigation regarding the storage of spent nuclear fuel.  The litigation is discussed in more detail in Part II, Item 5, “Spent Nuclear Fuel”
·  
the timing of payments to vendors;
·  
a $30.6 million June 2012 refund to AmerenUE, as discussed above; and
·  
a $15.4 million decrease in pension contributions in 2013 as compared to the same period in prior year.

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.

Investing Activities

Net cash flow used in investing activities increased $110.6 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to:

·  
approximately $68 million in spending related to the generator stator incident at ANO, as discussed above;
·  
money pool activity; and
·  
$39.6 million in storm restoration spending in 2013 resulting from the December 2012 winter storm.

The increase was partially offset by a decrease in transmission construction expenditures due to higher reliability work performed in 2012 and 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.

Increases in Entergy Arkansas’s receivable from the money pool are a use of cash flow, and Entergy Arkansas’s receivable from the money pool increased by $45.3 million for the nine months ended September 30, 2013 compared to decreasing by $9.9 million for the nine months ended September 30, 2012.  The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Financing Activities

Net cash flow provided by financing activities increased $237.3 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to:

·  
the issuance of $250 million of 3.05% Series first mortgage bonds in May 2013 and $125 million of 4.75% Series first mortgage bonds in June 2013;
·  
the net repayment of $16.6 million of borrowings on the Entergy Arkansas nuclear fuel company variable interest entity credit facility compared to net borrowings of $18.8 million in 2012; and
·  
borrowings on a $250 million term loan credit facility entered into in July 2013.

The increase was partially offset by:

·  
the retirement, at maturity, of $30 million 9% Series H notes by the Entergy Arkansas nuclear fuel company variable interest entity in June 2013; and
·  
the retirement, at maturity, of $300 million of 5.40% Series first mortgage bonds in August 2013.


 
99

Entergy Arkansas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis


Capital Structure

Entergy Arkansas’s capitalization is balanced between equity and debt, as shown in the following table.  The increase in the debt to capital ratio for Entergy Arkansas as of September 30, 2013 is primarily due to an increase in long-term debt as a result of the issuance of $250 million of 3.05% Series first mortgage bonds in May 2013 and $125 million of 4.75% Series first mortgage bonds in June 2013, and borrowings on a $250 million term loan credit facility entered into by Entergy Arkansas in July 2013.

   
September 30,
 2013
 
December 31,
2012
         
Debt to capital
 
57.3% 
 
56.0% 
Effect of excluding the securitization bonds
 
(1.0%)
 
(1.2%)
Debt to capital, excluding securitization bonds (a)
 
56.3% 
 
54.8% 
Effect of subtracting cash
 
(0.5%)
 
(0.4%)
Net debt to net capital, excluding securitization bonds (a)
 
55.8% 
 
54.4% 

(a)
Calculation excludes the securitization bonds, which are non-recourse to Entergy Arkansas.

Net debt consists of debt less cash and cash equivalents.  Debt consists of short-term borrowings and long-term debt, including the currently maturing portion.  Capital consists of debt, preferred stock without sinking fund, and common equity.  Net capital consists of capital less cash and cash equivalents.  Entergy Arkansas uses the 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 Arkansas’s financial condition because the securitization bonds are non-recourse to Entergy Arkansas, as more fully described in Note 5 to the financial statements in the Form 10-K.  Entergy Arkansas 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 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 is developing its capital investment plan for 2014 through 2016 and currently anticipates making $1.7 billion in capital investments during that period.  In addition to routine capital spending to maintain operations, the capital investment plan includes specific investments and initiatives such as NRC post-Fukushima requirements, potential scrubbers at the White Bluff plant to meet pending Arkansas state requirements under the Clean Air Visibility Rule and compliance with the EPA’s Mercury and Air Toxic Standard rule, and transmission spending to support economic development projects, reliability, and new compliance projects.

Entergy Arkansas has obtained short-term borrowing authorization from the FERC under which it may borrow through October 2015, up to the aggregate amount, at any one time outstanding, of $250 million.  See Note 4 to the financial statements for further discussion of Entergy Arkansas’s short-term borrowing limits.  Entergy Arkansas has also obtained an order from the APSC authorizing long-term securities issuances through December 2015.  Entergy Arkansas has also obtained long-term financing authorization from the FERC that extends through October 2015 for issuances by its nuclear fuel company variable interest entity.



 
100

Entergy Arkansas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis


Entergy Arkansas’s receivables from the money pool were as follows:

September 30,
2013
 
December 31,
2012
 
September 30,
2012
 
December 31,
2011
(In Thousands)
             
$53,375
 
$8,035
 
$7,487
 
$17,362

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 March 2018.  Entergy Arkansas also has a $20 million credit facility scheduled to expire in April 2014.  No borrowings were outstanding under the credit facilities as of September 30, 2013.  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 $85 million scheduled to expire in June 2016.  As of September 30, 2013, $20.1 million in letters of credit were outstanding under the credit facility to support a like amount of commercial paper issued by the Entergy Arkansas nuclear fuel company variable interest entity.  See Note 4 to the financial statements for additional discussion of the nuclear fuel company variable interest entity credit facility.

In January 2013, Entergy Arkansas arranged for the issuance by (i) Independence County, Arkansas of $45 million of 2.375% Pollution Control Revenue Refinancing Bonds (Entergy Arkansas, Inc. Project) Series 2013 due January 2021, and (ii) Jefferson County, Arkansas of $54.7 million of 1.55% Pollution Control Revenue Refunding Bonds (Entergy Arkansas, Inc. Project) Series 2013 due October 2017, each of which series is secured by a separate series of non-interest bearing first mortgage bonds of Entergy Arkansas.  The proceeds of these issuances were applied to the refunding of outstanding series of pollution control revenue bonds previously issued by the respective issuers.

In May 2013, Entergy Arkansas issued $250 million of 3.05% Series first mortgage bonds due June 2023. Entergy Arkansas used the proceeds to pay, at maturity, a portion of its $300 million 5.40% Series first mortgage bonds due August 2013 and for general corporate purposes.

In June 2013, Entergy Arkansas issued $125 million of 4.75% Series first mortgage bonds due June 2063. Entergy Arkansas used the proceeds to pay, at maturity, a portion of its $300 million 5.40% Series first mortgage bonds due August 2013 and for general corporate purposes.

In June 2013, the Entergy Arkansas nuclear fuel company variable interest entity redeemed, at maturity, its $30 million 9% Series H notes.

In July 2013, Entergy Arkansas entered into a $250 million term loan credit facility terminating January 26, 2015 with the collateral support of a series of $255 million non-interest bearing Entergy Arkansas first mortgage bonds.  On July 31, 2013, Entergy Arkansas borrowed $250 million against the credit facility.  Entergy Arkansas used the borrowings to pay, at maturity, a portion of its $300 million 5.40% Series first mortgage bonds due August 2013 and for general corporate purposes.

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.  Following are updates to that discussion.


 
101

Entergy Arkansas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis


2013 Base Rate Filing

In March 2013, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs.  Recognizing that the final structure of Entergy Arkansas’s transmission business has not been determined, the filing presents two alternative scenarios for the APSC to establish the appropriate level of rates for Entergy Arkansas.  In the primary scenario, which assumes that Entergy Arkansas will transition to MISO in December 2013, Entergy Arkansas requests a rate increase of $174 million, including $49 million of revenue being transferred from collection in riders to base rates.  The alternate scenario, which also assumes completion of the proposed spin-merge of the transmission business with ITC, reflects a $218 million total rate increase request.  Both scenarios propose a new transmission rider and a capacity cost recovery rider.  The filing requests a 10.4% return on common equity.  In September 2013 Entergy Arkansas filed testimony reflecting an updated rate increase request of $145 million in the primary scenario, with no change to its requested return on common equity of 10.4%.  Hearings in the proceeding began in October 2013, and an APSC decision is pending.   New rates are expected to become effective by January 2014.

Opportunity Sales Proceeding

See Note 2 to the financial statements herein for an update to the discussion of the opportunity sales proceeding.

Federal Regulation

See “System Agreement” and “Entergy’s Proposal to Join MISO” in the “Rate, Cost-recovery, and Other Regulation – Federal Regulation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for updates to the Federal Regulation discussion in the Form 10-K.

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, unbilled revenue, and qualified pension and other postretirement benefits.



 
CONSOLIDATED INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
   
Three Months Ended
   
Nine Months Ended
 
   
2013
   
2012
   
2013
   
2012
 
   
(In Thousands)
   
(In Thousands)
 
                         
OPERATING REVENUES
                       
Electric
  $ 647,671     $ 656,201     $ 1,698,716     $ 1,633,401  
                                 
OPERATING EXPENSES
                               
Operation and Maintenance:
                               
   Fuel, fuel-related expenses, and
                               
     gas purchased for resale
    113,523       116,026       321,373       362,954  
   Purchased power
    131,736       145,305       369,643       318,474  
   Nuclear refueling outage expenses
    9,403       11,891       29,031       35,441  
   Other operation and maintenance
    147,513       140,730       438,021       406,561  
Decommissioning
    10,847       10,198       32,044       30,128  
Taxes other than income taxes
    24,303       26,676       69,073       69,073  
Depreciation and amortization
    58,083       55,092       172,059       165,697  
Other regulatory credits - net
    (5,418 )     (2,553 )     (14,465 )     (35,478 )
TOTAL
    489,990       503,365       1,416,779       1,352,850  
                                 
OPERATING INCOME
    157,681       152,836       281,937       280,551  
                                 
OTHER INCOME
                               
Allowance for equity funds used during construction
    2,902       2,258       7,852       6,491  
Interest and investment income
    1,525       3,861       18,411       11,233  
Miscellaneous - net
    (629 )     (496 )     (2,573 )     (3,139 )
TOTAL
    3,798       5,623       23,690       14,585  
                                 
INTEREST EXPENSE
                               
Interest expense
    23,253       20,532       69,290       61,707  
Allowance for borrowed funds used during construction
    (744 )     (648 )     (2,473 )     (1,724 )
TOTAL
    22,509       19,884       66,817       59,983  
                                 
INCOME BEFORE INCOME TAXES
    138,970       138,575       238,810       235,153  
                                 
Income taxes
    56,393       56,024       101,031       92,973  
                                 
NET INCOME
    82,577       82,551       137,779       142,180  
                                 
Preferred dividend requirements
    1,718       1,718       5,155       5,155  
                                 
EARNINGS APPLICABLE TO
                               
COMMON STOCK
  $ 80,859     $ 80,833     $ 132,624     $ 137,025  
                                 
See Notes to Financial Statements.
                               

 
 
 
 
 
 
 
 
 
 
 
 
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CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2013 and 2012
(Unaudited)
             
   
2013
   
2012
 
   
(In Thousands)
 
             
OPERATING ACTIVITIES
           
Net income
  $ 137,779     $ 142,180  
Adjustments to reconcile net income to net cash flow provided by operating activities:
 
  Depreciation, amortization, and decommissioning, including nuclear fuel amortization
    263,176       266,755  
  Deferred income taxes, investment tax credits, and non-current taxes accrued
    99,442       97,641  
  Changes in assets and liabilities:
               
    Receivables
    (70,219 )     (86,046 )
    Fuel inventory
    16,740       3,130  
    Accounts payable
    (12,996 )     (144,562 )
    Prepaid taxes and taxes accrued
    (222,118 )     (9,302 )
    Interest accrued
    (9,760 )     (11,061 )
    Deferred fuel costs
    26,672       88,097  
    Other working capital accounts
    (12,324 )     32,465  
    Provisions for estimated losses
    200       171  
    Other regulatory assets
    2,515       51,089  
    Pension and other postretirement liabilities
    (25,332 )     (40,976 )
    Other assets and liabilities
    7,982       (51,661 )
Net cash flow provided by operating activities
    201,757       337,920  
                 
INVESTING ACTIVITIES
               
Construction expenditures
    (365,511 )     (273,010 )
Allowance for equity funds used during construction
    10,587       9,002  
Nuclear fuel purchases
    (73,151 )     (134,928 )
Proceeds from sale of nuclear fuel
    36,478       76,042  
Proceeds from nuclear decommissioning trust fund sales
    173,431       103,394  
Investment in nuclear decommissioning trust funds
    (178,516 )     (110,520 )
Changes in money pool receivable - net
    (45,340 )     9,875  
Remittances to transition charge account
    7,356       (11,987 )
Payments from transition charge account
    (10,849 )     7,476  
Litigation proceeds for reimbursement of spent nuclear fuel storage costs
    10,271       -  
Net cash flow used in investing activities
    (435,244 )     (324,656 )
                 
FINANCING ACTIVITIES
               
Proceeds from the issuance of long-term debt
    716,670       -  
Retirement of long-term debt
    (435,896 )     (5,990 )
Changes in short-term borrowings - net
    (16,602 )     18,776  
Dividends paid:
               
  Common stock
    (15,000 )     -  
  Preferred stock
    (5,155 )     (5,155 )
Other
    -       (872 )
Net cash flow provided by financing activities
    244,017       6,759  
                 
Net increase in cash and cash equivalents
    10,530       20,023  
                 
Cash and cash equivalents at beginning of period
    34,533       22,599  
                 
Cash and cash equivalents at end of period
  $ 45,063     $ 42,622  
                 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
         
Cash paid (received) during the period for:
               
  Interest - net of amount capitalized
  $ 75,022     $ 68,990  
  Income taxes
  $ 211,415     $ (6,897 )
                 
See Notes to Financial Statements.
               
                 
 

 
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2013 and December 31, 2012
(Unaudited)
             
   
2013
   
2012
 
   
(In Thousands)
 
             
CURRENT ASSETS
           
Cash and cash equivalents:
           
  Cash
  $ 3,342     $ 9,597  
  Temporary cash investments
    41,721       24,936  
    Total cash and cash equivalents
    45,063       34,533  
Securitization recovery trust account
    7,896       4,403  
Accounts receivable:
               
  Customer
    130,206       98,036  
  Allowance for doubtful accounts
    (28,736 )     (28,343 )
  Associated companies
    127,571       67,277  
  Other
    71,310       71,956  
  Accrued unbilled revenues
    97,036       72,902  
    Total accounts receivable
    397,387       281,828  
Accumulated deferred income taxes
    234       72,196  
Deferred fuel costs
    70,633       97,305  
Fuel inventory - at average cost
    32,235       48,975  
Materials and supplies - at average cost
    151,418       148,682  
Deferred nuclear refueling outage costs
    41,332       38,410  
Prepaid taxes
    7,149       -  
Prepayments and other
    61,281       10,586  
TOTAL
    814,628       736,918  
                 
OTHER PROPERTY AND INVESTMENTS
               
Decommissioning trust funds
    669,770       600,578  
Non-utility property - at cost (less accumulated depreciation)
    1,666       1,671  
Other
    41,182       41,182  
TOTAL
    712,618       643,431  
                 
UTILITY PLANT
               
Electric
    8,883,551       8,693,659  
Property under capital lease
    1,088       1,154  
Construction work in progress
    166,903       205,982  
Nuclear fuel
    284,280       303,825  
TOTAL UTILITY PLANT
    9,335,822       9,204,620  
Less - accumulated depreciation and amortization
    4,174,124       4,104,882  
UTILITY PLANT - NET
    5,161,698       5,099,738  
                 
DEFERRED DEBITS AND OTHER ASSETS
               
Regulatory assets:
               
  Regulatory asset for income taxes - net
    75,286       80,751  
  Other regulatory assets (includes securitization property of
         
       $83,856 as of September 30, 2013 and $93,238 as of
         
       December 31, 2012)
    1,224,586       1,221,636  
Other
    41,779       36,971  
TOTAL
    1,341,651       1,339,358  
                 
TOTAL ASSETS
  $ 8,030,595     $ 7,819,445  
                 
See Notes to Financial Statements.
               
 
 
ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2013 and December 31, 2012
(Unaudited)
                 
      2013       2012  
   
(In Thousands)
 
                 
CURRENT LIABILITIES
               
Currently maturing long-term debt
  $ 70,000     $ 330,000  
Short-term borrowings
    20,133       36,735  
Accounts payable:
               
  Associated companies
    49,802       39,288  
  Other
    140,144       200,964  
Customer deposits
    85,760       85,198  
Taxes accrued
    -       214,969  
Accumulated deferred income taxes
    9,794       5,927  
Interest accrued
    18,658       28,418  
Other
    63,720       45,208  
TOTAL
    458,011       986,707  
                 
NON-CURRENT LIABILITIES
               
Accumulated deferred income taxes and taxes accrued
    1,859,020       1,829,281  
Accumulated deferred investment tax credits
    39,456       40,947  
Other regulatory liabilities
    191,842       143,901  
Decommissioning
    712,756       680,712  
Accumulated provisions
    6,022       5,822  
Pension and other postretirement liabilities
    589,362       614,805  
Long-term debt (includes securitization bonds of $95,364 as of
         
September 30, 2013 and $101,547 as of December 31, 2012)
    2,342,168       1,793,895  
Other
    18,368       27,409  
TOTAL
    5,758,994       5,136,772  
                 
Commitments and Contingencies
               
                 
Preferred stock without sinking fund
    116,350       116,350  
                 
COMMON EQUITY
               
Common stock, $0.01 par value, authorized 325,000,000
         
  shares; issued and outstanding 46,980,196 shares in 2013
         
  and 2012
    470       470  
Paid-in capital
    588,444       588,444  
Retained earnings
    1,108,326       990,702  
TOTAL
    1,697,240       1,579,616  
                 
TOTAL LIABILITIES AND EQUITY
  $ 8,030,595     $ 7,819,445  
                 
See Notes to Financial Statements.
               

 

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON EQUITY
For the Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
   
Common Equity
       
   
Common
Stock
   
Paid-in
Capital
   
Retained
Earnings
   
Total
 
   
(In Thousands)
 
                         
Balance at December 31, 2011
  $ 470     $ 588,444     $ 855,210     $ 1,444,124  
                                 
Net income
    -       -       142,180       142,180  
Preferred stock dividends
    -       -       (5,155 )     (5,155 )
                                 
Balance at September 30, 2012
  $ 470     $ 588,444     $ 992,235     $ 1,581,149  
                                 
                                 
Balance at December 31, 2012
  $ 470     $ 588,444     $ 990,702     $ 1,579,616  
                                 
Net income
    -       -       137,779       137,779  
Common stock dividends
    -       -       (15,000 )     (15,000 )
Preferred stock dividends
    -       -       (5,155 )     (5,155 )
                                 
Balance at September 30, 2013
  $ 470     $ 588,444     $ 1,108,326     $ 1,697,240  
                                 
See Notes to Financial Statements.
                               

 
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
                         
   
Three Months Ended
   
Increase/
       
Description
 
2013
   
2012
   
(Decrease)
 
%
 
   
(Dollars In Millions)
       
Electric Operating Revenues:
                   
  Residential
  $ 248     $ 276     $ (28 )     (10 )
  Commercial
    141       148       (7 )     (5 )
  Industrial
    131       137       (6 )     (4 )
  Governmental
    5       4       1       25  
    Total retail
    525       565       (40 )     (7 )
  Sales for resale:
                               
     Associated companies
    89       71       18       25  
     Non-associated companies
    19       19       -       -  
  Other
    15       1       14       1,400  
    Total
  $ 648     $ 656     $ (8 )     (1 )
                                 
Billed Electric Energy
                               
 Sales (GWh):
                               
  Residential
    2,367       2,646       (279 )     (11 )
  Commercial
    1,767       1,859       (92 )     (5 )
  Industrial
    1,906       1,967       (61 )     (3 )
  Governmental
    67       72       (5 )     (7 )
    Total retail
    6,107       6,544       (437 )     (7 )
  Sales for resale:
                               
     Associated companies
    2,094       1,581       513       32  
     Non-associated companies
    181       292       (111 )     (38 )
    Total
    8,382       8,417       (35 )     -  
                                 
                                 
   
Nine Months Ended
   
Increase/
         
Description
    2013       2012    
(Decrease)
 
%
 
   
(Dollars In Millions)
         
Electric Operating Revenues:
                         
  Residential
  $ 608     $ 613     $ (5 )     (1 )
  Commercial
    358       364       (6 )     (2 )
  Industrial
    328       335       (7 )     (2 )
  Governmental
    15       15       -       -  
    Total retail
    1,309       1,327       (18 )     (1 )
  Sales for resale:
                               
     Associated companies
    267       221       46       21  
     Non-associated companies
    56       28       28       100  
  Other
    67       57       10       18  
    Total
  $ 1,699     $ 1,633     $ 66       4  
                                 
Billed Electric Energy
                               
 Sales (GWh):
                               
  Residential
    6,164       6,270       (106 )     (2 )
  Commercial
    4,503       4,682       (179 )     (4 )
  Industrial
    5,068       5,248       (180 )     (3 )
  Governmental
    182       198       (16 )     (8 )
    Total retail
    15,917       16,398       (481 )     (3 )
  Sales for resale:
                               
     Associated companies
    6,202       5,450       752       14  
     Non-associated companies
    539       800       (261 )     (33 )
    Total
    22,658       22,648       10       -  
                                 
 
 


ENTERGY GULF STATES LOUISIANA, L.L.C.

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS


Plan to Spin Off the Utility’s Transmission Business

See the “Plan to Spin Off the Utility’s Transmission Business” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K and herein for a discussion of Entergy’s plan to spin off its transmission business and merge it with a newly formed subsidiary of ITC Holdings Corp., including the planned retirement of debt and preferred securities.

Results of Operations

Net Income

Third Quarter 2013 Compared to Third Quarter 2012

Net income increased $12.4 million primarily due to higher net revenue and a lower effective income tax rate, partially offset by higher other operation and maintenance expenses, lower other income, and higher taxes other than income taxes.

Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Net income decreased $9.4 million primarily due to higher other operation and maintenance expenses, higher taxes other than income taxes, higher depreciation and amortization expenses, and a higher effective income tax rate, partially offset by higher net revenue.

Net Revenue

Third Quarter 2013 Compared to Third Quarter 2012

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges.  Following is an analysis of the change in net revenue comparing the third quarter 2013 to the third quarter 2012:

   
Amount
   
(In Millions)
     
2012 net revenue
 
$239.3 
Net wholesale revenue
 
5.6 
Retail electric price
 
4.8 
River Bend decommissioning trust
 
4.1 
Volume/weather
 
3.8 
Other
 
1.3 
2013 net revenue
 
$258.9 

The net wholesale revenue variance is primarily due to higher prices.

The retail electric price variance is primarily due to increased recovery of affiliate purchased power capacity costs through base rates set in the annual formula rate plan mechanism. Entergy Gulf States Louisiana’s formula rate plan is discussed in Note 2 to the financial statements herein and in the Form 10-K.

 
110

Entergy Gulf States Louisiana, L.L.C.
Management’s Financial Discussion and Analysis



The River Bend decommissioning trust variance is primarily due to the deferral of investment gains from the River Bend decommissioning trust in 2012 in accordance with regulatory treatment.  The prior year gains resulted in an increase in 2012 in other income and a corresponding decrease in regulatory charges with no effect on net income.

The volume/weather variance is primarily due to an increase of 163 GWh, or 3%, in billed electricity usage in the residential, commercial, and industrial sectors. The increase in the industrial usage was driven by the chemicals industry.

Gross operating revenues and fuel and purchased power expenses

Gross operating revenues increased primarily due to an increase of $61.2 million in fuel cost recovery revenues primarily due to higher fuel rates and an increase of $51.4 million in rider revenues primarily due to System Agreement credits to customers in 2012.  Entergy Gulf States Louisiana’s fuel and purchased power recovery mechanism is discussed in Note 2 to the financial statements in the Form 10-K.

Fuel and purchased power expenses increased primarily due to:

·  
an increase in deferred fuel expense due to the timing of receipt of System Agreement payments and credits to customers and higher fuel cost recovery revenues due to higher fuel rates as compared to the prior year. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of the System Agreement proceedings; and
·  
an increase in the average market price of purchased power and increased demand.

Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges.  Following is an analysis of the change in net revenue comparing the nine months ended September 30, 2013 to the nine months ended September 30, 2012:

   
Amount
   
(In Millions)
     
2012 net revenue
 
$653.7 
Louisiana Act 55 financing savings obligation
 
28.3 
Net wholesale revenue
 
7.8 
Other
 
2.0 
2013 net revenue
 
$691.8 

The Louisiana Act 55 financing savings obligation variance results from a regulatory charge recorded in the second quarter 2012 because Entergy Gulf States Louisiana is sharing with customers the savings from an IRS settlement related to the uncertain tax position regarding the Hurricane Katrina and Hurricane Rita Louisiana Act 55 financing.  See Note 3 to the financial statements in the Form 10-K for additional discussion of the tax settlement and savings obligation.

The net wholesale revenue variance is primarily due to higher prices.


 
111

Entergy Gulf States Louisiana, L.L.C.
Management’s Financial Discussion and Analysis


Gross operating revenues, fuel and purchased power expenses, and other regulatory charges

Gross operating revenues increased primarily due to:

·  
an increase of $138.8 million in fuel cost recovery revenues primarily due to higher fuel rates;
·  
an increase of $69.5 million in rider revenues primarily due to System Agreement credits to customers in 2012; and
·  
an increase of $12.3 million in gross wholesale revenues primarily due to higher prices.

Entergy Gulf States Louisiana’s fuel and purchased power recovery mechanism is discussed in Note 2 to the financial statements in the Form 10-K.

Fuel and purchased power expenses increased primarily due to:

·  
an increase in the average market price of purchased power and increased demand; and
·  
an increase in deferred fuel expense due to the timing of receipt of System Agreement payments and credits to customers and higher fuel cost recovery revenues due to higher fuel rates as compared to the prior year. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of the System Agreement proceedings.

Other regulatory charges decreased primarily due to a regulatory charge recorded in the second quarter 2012 because Entergy Gulf States Louisiana is sharing with customers the savings from an IRS settlement related to the uncertain tax position regarding the Hurricane Katrina and Hurricane Rita Louisiana Act 55 financing. See Note 3 to the financial statements in the Form 10-K for additional discussion of the tax settlement and savings obligation.

Other Income Statement Variances

Third Quarter 2013 Compared to Third Quarter 2012

Other operation and maintenance expenses increased primarily due to:

·  
an increase of $5.5 million in compensation and benefits costs primarily due to a settlement charge, recognized in September 2013, related to the payment of lump sum benefits out of the non-qualified pension plan and a decrease in the discount rates used to determine net periodic pension and other postretirement benefit costs.  See "MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates" in the Form 10-K and Note 6 to the financial statements herein for further discussion of benefits costs;
·  
an increase of $2.3 million in loss reserves;
·  
an increase of $1.8 million in nuclear generation expenses primarily due to higher labor costs;
·  
an increase of $1.7 million in fossil-fueled generation expenses due to an overall higher scope of work done during plant outages as compared to the prior year; and
·  
several individually insignificant items.

Other income decreased primarily due to lower realized gains in 2013 on the River Bend decommissioning trust fund investments.  There is no effect on net income as these investment gains are offset by a corresponding amount of regulatory charges.


 
112

Entergy Gulf States Louisiana, L.L.C.
Management’s Financial Discussion and Analysis


Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Other operation and maintenance expenses increased primarily due to:

·  
an increase of $11.4 million in compensation and benefits costs primarily due to a decrease in the discount rates used to determine net periodic pension and other postretirement benefit costs and a settlement charge, recognized in September 2013, related to the payment of lump sum benefits out of the non-qualified pension plan.  See "MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates" in the Form 10-K and Note 6 to the financial statements herein for further discussion of benefits costs;
·  
the deferral recorded in the second quarter 2012, as approved by the LPSC and the FERC, of costs related to the transition and implementation of joining the MISO RTO, which reduced expenses by $4.2 million in 2012;
·  
an increase of $4.9 million in nuclear generation expenses primarily due to higher labor costs including higher contract labor;
·  
an increase of $2.7 million in loss reserves;
·  
an increase of $2.2 million in fossil-fueled generation expenses due to an overall higher scope of work done during plant outages as compared to the prior year; and
·  
several individually insignificant items.

Income Taxes

The effective income tax rate was 15.6% for the third quarter 2013 and 27.3% for the nine months ended September 30, 2013. The differences in the effective income tax rates for the third quarter 2013 and the nine months ended September 30, 2013 versus the federal statutory rate of 35% were due to the reversal of a portion of the provision for uncertain tax positions and book and tax differences related to the non-taxable income distributions earned on preferred membership interests, partially offset by state income taxes.

The effective income tax rate was 36.8% for the third quarter 2012 and 24.2% for the nine months ended September 30, 2012.  The difference in the effective income tax rate for the third quarter 2012 versus the federal statutory rate of 35% was due to state income taxes and the provision for uncertain tax positions, partially offset by book and tax differences related to the non-taxable income distributions earned on preferred membership interests. The difference in the effective income tax rate for the nine months ended September 30, 2012 versus the federal statutory rate of 35% was due to book and tax differences related to the non-taxable income distributions earned on preferred membership interests and the reversal of the provision for uncertain tax positions related to an IRS settlement on how to treat the Louisiana Act 55 financing of the Hurricane Katrina and Hurricane Rita storm costs, partially offset by state income taxes.

Hurricane Isaac

See "MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Hurricane Isaac" in the Form 10-K for a discussion of Hurricane Isaac and the damage caused to Entergy Gulf States Louisiana’s service area in August 2012.  In April 2013, Entergy Gulf States Louisiana and Entergy Louisiana filed a joint application with the LPSC relating to Hurricane Isaac system restoration costs.  Specifically, Entergy Gulf States Louisiana requested that the LPSC determine the amount of such costs that were prudently incurred and are, thus, eligible for recovery from customers.  Including carrying costs and additional storm escrow funds, Entergy Gulf States Louisiana is seeking determination that $73.8 million in system restoration costs were prudently incurred.  Entergy Gulf States Louisiana intends to replenish its storm escrow accounts to $90 million primarily through traditional debt markets and has requested special rate treatment of any borrowings for that purpose.  In May 2013, Entergy Gulf States Louisiana filed a supplemental application proposing a specific means to finance system restoration costs and related requests.  Entergy Gulf States Louisiana is proposing to finance Hurricane Isaac restoration costs through Louisiana Act 55 financing, which was the same method it used for Hurricanes Katrina, Rita, Gustav, and Ike.


 
113

Entergy Gulf States Louisiana, L.L.C.
Management’s Financial Discussion and Analysis


The LPSC Staff filed direct testimony in September 2013 concluding that Hurricane Isaac system restoration costs incurred by Entergy Gulf States Louisiana and Entergy Louisiana were reasonable and prudent, subject to proposed minor adjustments which totaled approximately 1% of each company’s costs.  The LPSC Staff also supported the requests to re-establish storm reserves of $90 million for Entergy Gulf States Louisiana and $200 million for Entergy Louisiana.  One intervenor filed testimony recommending storm reserve levels of $70 million for Entergy Gulf States Louisiana and $100 million for Entergy Louisiana, but takes no position on the prudence of the Hurricane Isaac system restoration costs.  An evidentiary hearing is scheduled in December 2013, with an LPSC decision expected in 2014.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2013 and 2012 were as follows:

   
2013
 
2012
   
(In Thousands)
         
Cash and cash equivalents at beginning of period
 
$35,686 
 
$24,845 
         
Cash flow provided by (used in):
       
 
Operating activities
 
270,298 
 
391,711 
 
Investing activities
 
(261,281)
 
(145,984)
 
Financing activities
 
(43,933)
 
(94,008)
Net increase (decrease) in cash and cash equivalents
 
(34,916)
 
151,719 
         
Cash and cash equivalents at end of period
 
$770 
 
$176,564 

Operating Activities

Net cash flow provided by operating activities decreased $121.4 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to:

·  
income tax payments of $62.4 million in the nine months ended September 30, 2013. Entergy Gulf States Louisiana had income tax payments in 2013 in accordance with the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement. The payments resulted primarily from the reversal of temporary differences for which Entergy Gulf States Louisiana had previously claimed a tax deduction;
·  
higher nuclear refueling outage spending at River Bend.  River Bend had a refueling outage in 2013 and did not have one in 2012; and
·  
the timing of collections from customers.

Investing Activities

Net cash flow used in investing activities increased $115.3 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to:

·  
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;
·  
$51 million in proceeds in 2012 from the sale of a portion of Entergy Gulf States Louisiana’s investment in Entergy Holdings Company’s Class A preferred membership interests to a third party;
·  
an increase in nuclear construction expenditures as a result of spending on nuclear projects during the River Bend refueling outage in 2013; and
·  
an increase in transmission construction expenditures due to additional reliability work performed in 2013.
 
 
114

Entergy Gulf States Louisiana, L.L.C.
Management’s Financial Discussion and Analysis


These increases were partially offset by:

·  
the withdrawal of $65.5 million from the storm reserve escrow account in 2013;
·  
a decrease in distribution construction expenditures due to prior year Hurricane Isaac spending; and
·  
a decrease in fossil-fueled generation construction expenditures as a result of decreased scope of work in 2013.

Financing Activities

Net cash flow used in financing activities decreased $50.1 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to:

·  
$31 million in credit borrowings for the nine months ended September 30, 2013 compared to payments of $29.4 million on credit borrowings for the nine months ended September 30, 2012 against the nuclear fuel company variable interest entity credit facility; and
·  
money pool activity.

The decrease was offset by:

·  
an increase of $52.5 million in common equity distributions;
·  
net cash redemptions of $5.2 million of long-term debt for the nine months ended September 30, 2013; and
·  
net cash issuances of $3.4 million of long-term debt for the nine months ended September 30, 2012.

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

Increases in Entergy Gulf States Louisiana’s payable to the money pool are a source of cash flow, and Entergy Gulf States Louisiana’s payable to the money pool increased by $50.8 million for the nine months ended September 30, 2013. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Capital Structure

Entergy Gulf States Louisiana’s capitalization is balanced between equity and debt, as shown in the following table.
 
   
September 30,
2013
 
December 31,
2012
         
Debt to capital
 
52.7% 
 
52.3% 
Effect of subtracting cash
 
-% 
 
(0.6%)
Net debt to net capital
 
52.7% 
 
51.7% 

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 equity.  Net capital consists of capital less cash and cash equivalents.  Entergy Gulf States Louisiana 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 Gulf States Louisiana’s financial condition.  Entergy Gulf States Louisiana uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Gulf States Louisiana’s financial condition because net debt indicates Entergy Gulf States Louisiana’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.


 
115

Entergy Gulf States Louisiana, L.L.C.
Management’s Financial Discussion and Analysis


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 Gulf States Louisiana’s uses and sources of capital.  Following are updates to the information provided in the Form 10-K.  Entergy Gulf States Louisiana is developing its capital investment plan for 2014 through 2016 and currently anticipates making $861 million in capital investments during that period.  In addition to routine capital spending to maintain operations, the capital investment plan includes specific investments and initiatives such as NRC post-Fukushima requirements and transmission spending to support economic development projects, reliability, and new compliance projects.

Entergy Gulf States Louisiana obtained short-term borrowing authorization from the FERC under which it may borrow through October 2015, up to the aggregate amount, at any one time outstanding, of $200 million.  See Note 4 to the financial statements for further discussion of Entergy Gulf States Louisiana’s short-term borrowing limits.  Entergy Gulf States Louisiana has also obtained an order from the FERC authorizing long-term securities issuances through October 2015.  Entergy Gulf States Louisiana has also obtained long-term financing authorization from the FERC that extends through October 2015 for issuances by its nuclear fuel company variable interest entity.

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

September 30,
2013
 
December 31,
2012
 
September 30,
2012
 
December 31,
2011
(In Thousands)
             
($57,835)
 
($7,074)
 
$32,161
 
$23,596

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

Entergy Gulf States Louisiana has a credit facility in the amount of $150 million scheduled to expire in March 2018.  No borrowings were outstanding under the facility as of September 30, 2013.  See Note 4 to the financial statements herein for additional discussion of the credit facility.

The Entergy Gulf States Louisiana nuclear fuel company variable interest entity has a credit facility in the amount of $100 million scheduled to expire in June 2016.  As of September 30, 2013, $31 million was outstanding on the variable interest entity credit facility.  See Note 4 to the financial statements for additional discussion of the variable interest entity credit facility.

In February 2013 the Entergy Gulf States Louisiana nuclear fuel company variable interest entity issued $70 million of 3.38% Series R notes due August 2020.  The Entergy Gulf States Louisiana nuclear fuel company variable interest entity used the proceeds principally to purchase additional nuclear fuel.

In May 2013 the Entergy Gulf States Louisiana nuclear fuel company variable interest entity redeemed, at maturity, its $75 million 5.56% Series N notes.

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.  Following are updates to that discussion.


 
116

Entergy Gulf States Louisiana, L.L.C.
Management’s Financial Discussion and Analysis


Retail Rates - Electric

In November 2011 the LPSC approved a one-year extension of Entergy Gulf States Louisiana’s formula rate plan.  In May 2012, Entergy Gulf States Louisiana made its formula rate plan filing with the LPSC for the 2011 test year.  The filing reflected an 11.94% earned return on common equity, which is above the earnings bandwidth and would indicate a $6.5 million cost of service rate decrease was necessary under the formula rate plan.  The filing also reflected a $22.9 million rate decrease for the incremental capacity rider.  Subsequently, in August 2012, Entergy Gulf States Louisiana submitted a revised filing that reflected an earned return on common equity of 11.86% indicating that a $5.7 million cost of service rate decrease is necessary under the formula rate plan.  The revised filing also indicates that a reduction of $20.3 million should be reflected in the incremental capacity rider.  The rate reductions were implemented, subject to refund, effective for bills rendered the first billing cycle of September 2012.  Subsequently, in December 2012, Entergy Gulf States Louisiana submitted a revised evaluation report that reflects expected retail jurisdictional cost of $16.9 million for the first-year capacity charges for the purchase from Entergy Louisiana of one-third of Acadia Unit 2 capacity and energy.  This rate change was implemented effective with the first billing cycle of January 2013.  The 2011 test year filings, as revised, were approved by the LPSC in February 2013.  In April 2013, Entergy Gulf States Louisiana submitted a revised evaluation report increasing the incremental capacity rider by approximately $7.3 million to reflect the cost of an additional capacity contract.

See Note 2 to the financial statements in the Form 10-K for a discussion of the base rate case filed by Entergy Gulf States Louisiana with the LPSC in February 2013.  In April 2013 the LPSC established a procedural schedule providing for hearings in November 2013, with a decision by the LPSC expected in 2014.  On July 26, 2013, with the concurrence of Entergy Gulf States Louisiana based upon an expected 60-day delay of the procedural schedule, the ALJ suspended the procedural schedule pending resolution of the appeal by Entergy Gulf States Louisiana, Entergy Louisiana and the LPSC staff regarding the ALJ’s denial of a motion to consolidate the rate cases of Entergy Gulf States Louisiana and Entergy Louisiana.  At an August 2013 meeting the LPSC rejected the proposed consolidation.  The base rate case is currently scheduled for an evidentiary hearing in February 2014.  An extension of the deadline for the filing of the staff’s and intervenors’ testimony was granted to allow for settlement negotiations, which are ongoing.

Retail Rates - Gas

In January 2013, Entergy Gulf States Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2012.  The filing showed an earned return on common equity of 11.18%, which resulted in a $43 thousand rate reduction.  In March 2013 the LPSC Staff issued its proposed findings and recommended two adjustments.  The first is to normalize property insurance expense, and the second is to modify the return on equity for gas operations to reflect the return on equity that ultimately is approved by the LPSC in the investigation previously initiated by the LPSC to review the return on equity for Louisiana gas utilities.  Entergy Gulf States Louisiana and the LPSC Staff reached agreement regarding the LPSC Staff’s proposed adjustments.  As reflected in an unopposed joint report of proceedings filed by Entergy Gulf States Louisiana and the LPSC Staff on May 16, 2013, Entergy Gulf States Louisiana accepted, with modification, the LPSC Staff’s proposed adjustment to property insurance expense and agreed to: (1) a three-year extension of the gas rate stabilization plan with a midpoint return on equity of 9.95%, with a first year midpoint reset; (2) dismissal of the docket initiated by the LPSC to evaluate the allowed return on equity for Entergy Gulf States Louisiana’s gas rate stabilization plan; and (3) presentation to the LPSC by November 2014 by Entergy Gulf States Louisiana and the LPSC Staff of their recommendation for implementation of an infrastructure rider to recover expenditures associated with strategic plant investment.  The LPSC approved the agreement in May 2013.

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.


 
117

Entergy Gulf States Louisiana, L.L.C.
Management’s Financial Discussion and Analysis


Federal Regulation

See “System Agreement” and “Entergy’s Proposal to Join MISO” in the “Rate, Cost-recovery, and Other Regulation – Federal Regulation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for updates to the Federal Regulation discussion in the Form 10-K.

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 Gulf States Louisiana’s accounting for nuclear decommissioning costs, unbilled revenue, and qualified pension and other postretirement benefits.




INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
   
Three Months Ended
   
Nine Months Ended
 
   
2013
   
2012
   
2013
   
2012
 
   
(In Thousands)
   
(In Thousands)
 
                         
OPERATING REVENUES
                       
Electric
  $ 549,123     $ 425,999     $ 1,428,155     $ 1,201,178  
Natural gas
    9,208       8,452       42,492       34,251  
TOTAL
    558,331       434,451       1,470,647       1,235,429  
                                 
OPERATING EXPENSES
                               
Operation and Maintenance:
                               
   Fuel, fuel-related expenses, and
                               
     gas purchased for resale
    104,932       34,821       213,270       131,248  
   Purchased power
    194,455       156,398       560,531       417,909  
   Nuclear refueling outage expenses
    5,419       4,415       14,955       13,147  
   Other operation and maintenance
    105,107       89,446       300,012       267,505  
Decommissioning
    4,005       3,783       11,845       11,187  
Taxes other than income taxes
    21,346       19,141       60,729       55,728  
Depreciation and amortization
    37,703       36,958       113,002       109,345  
Other regulatory charges - net
    80       3,928       5,080       32,536  
TOTAL
    473,047       348,890       1,279,424       1,038,605  
                                 
OPERATING INCOME
    85,284       85,561       191,223       196,824  
                                 
OTHER INCOME
                               
Allowance for equity funds used during construction
    2,171       1,760       5,630       6,512  
Interest and investment income
    9,428       13,442       34,239       33,350  
Miscellaneous - net
    (2,822 )     (1,615 )     (7,861 )     (6,727 )
TOTAL
    8,777       13,587       32,008       33,135  
                                 
INTEREST EXPENSE
                               
Interest expense
    20,498       20,406       60,971       62,297  
Allowance for borrowed funds used during construction
    (690 )     (652 )     (2,041 )     (2,516 )
TOTAL
    19,808       19,754       58,930       59,781  
                                 
INCOME BEFORE INCOME TAXES
    74,253       79,394       164,301       170,178  
                                 
Income taxes
    11,611       29,184       44,773       41,220  
                                 
NET INCOME
    62,642       50,210       119,528       128,958  
                                 
Preferred distribution requirements and other
    206       206       619       619  
                                 
                                 
EARNINGS APPLICABLE TO COMMON EQUITY
  $ 62,436     $ 50,004     $ 118,909     $ 128,339  
                                 
See Notes to Financial Statements.
                               

 
 
STATEMENTS OF COMPREHENSIVE INCOME
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
 
 
Three Months Ended
   
Nine Months Ended
 
   
2013
   
2012
   
2013
   
2012
 
   
(In Thousands)
   
(In Thousands)
 
                         
Net Income
  $ 62,642     $ 50,210     $ 119,528     $ 128,958  
Other comprehensive income
                               
   Pension and other postretirement liabilities
                               
         (net of tax expense of $778, $703, $2,342, and $8,247)
    963       862       2,880       12,397  
         Other comprehensive income
    963       862       2,880       12,397  
Comprehensive Income
  $ 63,605     $ 51,072     $ 122,408     $ 141,355  
                                 
                                 
See Notes to Financial Statements.
                               


 
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2013 and 2012
(Unaudited)
             
   
2013
   
2012
 
   
(In Thousands)
 
             
OPERATING ACTIVITIES
           
Net income
  $ 119,528     $ 128,958  
Adjustments to reconcile net income to net cash flow provided by operating activities:
         
  Depreciation, amortization, and decommissioning, including nuclear fuel amortization
    165,684       158,577  
  Deferred income taxes, investment tax credits, and non-current taxes accrued
    78,265       51,415  
  Changes in working capital:
               
    Receivables
    (59,583 )     63,699  
    Fuel inventory
    (1,868 )     (7,747 )
    Accounts payable
    13,921       42,149  
    Prepaid taxes and taxes accrued
    (61,290 )     67,987  
    Interest accrued
    5,302       5,696  
    Deferred fuel costs
    (8,867 )     (91,354 )
    Other working capital accounts
    (24,029 )     (11,434 )
  Changes in provisions for estimated losses
    (60,205 )     (3,100 )
  Changes in other regulatory assets
    31,754       (5,648 )
  Changes in pension and other postretirement liabilities
    4,877       (3,459 )
  Other
    66,809       (4,028 )
Net cash flow provided by operating activities
    270,298       391,711  
                 
INVESTING ACTIVITIES
               
Construction expenditures
    (205,162 )     (198,785 )
Allowance for equity funds used during construction
    5,630       6,512  
Nuclear fuel purchases
    (132,083 )     (41,592 )
Proceeds from the sale of nuclear fuel
    19,401       56,579  
Payment to storm reserve escrow account
    (25 )     (66 )
Receipts from storm reserve escrow account
    65,475       3,364  
Proceeds from nuclear decommissioning trust fund sales
    66,152       96,653  
Investment in nuclear decommissioning trust funds
    (80,669 )     (111,084 )
Change in money pool receivable - net
    -       (8,565 )
Proceeds from the sale of investment
    -       51,000  
Net cash flow used in investing activities
    (261,281 )     (145,984 )
                 
FINANCING ACTIVITIES
               
Proceeds from the issuance of long-term debt
    69,782       74,251  
Retirement of long-term debt
    (75,000 )     (70,840 )
Change in money pool payable - net
    50,761       -  
Changes in credit borrowings - net
    31,000       (29,400 )
Distributions paid:
               
  Common equity
    (119,900 )     (67,400 )
  Preferred membership interests
    (619 )     (619 )
Other
    43       -  
Net cash flow used in financing activities
    (43,933 )     (94,008 )
                 
Net increase (decrease) in cash and cash equivalents
    (34,916 )     151,719  
                 
Cash and cash equivalents at beginning of period
    35,686       24,845  
                 
Cash and cash equivalents at end of period
  $ 770     $ 176,564  
                 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
               
Cash paid during the period for:
               
  Interest - net of amount capitalized
  $ 53,512     $ 54,291  
  Income taxes
  $ 62,435     $ -  
                 
See Notes to Financial Statements.
               
                 


 
BALANCE SHEETS
ASSETS
September 30, 2013 and December 31, 2012
(Unaudited)
             
   
2013
   
2012
 
   
(In Thousands)
 
             
CURRENT ASSETS
           
Cash and cash equivalents:
           
  Cash
  $ 152     $ 35,085  
  Temporary cash investments
    618       601  
        Total cash and cash equivalents
    770       35,686  
Accounts receivable:
               
  Customer
    84,146       53,480  
  Allowance for doubtful accounts
    (793 )     (711 )
  Associated companies
    91,548       71,697  
  Other
    17,856       18,736  
  Accrued unbilled revenues
    61,614       51,586  
    Total accounts receivable
    254,371       194,788  
Deferred fuel costs
    7,919       -  
Fuel inventory - at average cost
    28,835       26,967  
Materials and supplies - at average cost
    122,664       121,289  
Deferred nuclear refueling outage costs
    31,598       5,953  
Prepaid taxes
    40,269       -  
Prepayments and other
    7,692       7,911  
TOTAL
    494,118       392,594  
                 
OTHER PROPERTY AND INVESTMENTS
               
Investment in affiliate preferred membership interests
    289,664       289,664  
Decommissioning trust funds
    537,624       477,391  
Non-utility property - at cost (less accumulated depreciation)
    172,098       165,410  
Storm reserve escrow account
    21,534       86,984  
Other
    14,046       13,404  
TOTAL
    1,034,966       1,032,853  
                 
UTILITY PLANT
               
Electric
    7,388,971       7,279,953  
Natural gas
    141,912       135,723  
Construction work in progress
    127,322       125,448  
Nuclear fuel
    208,839       146,768  
TOTAL UTILITY PLANT
    7,867,044       7,687,892  
Less - accumulated depreciation and amortization
    4,076,376       4,003,385  
UTILITY PLANT - NET
    3,790,668       3,684,507  
                 
DEFERRED DEBITS AND OTHER ASSETS
               
Regulatory assets:
               
  Regulatory asset for income taxes - net
    171,006       171,051  
  Other regulatory assets
    377,944       409,653  
  Deferred fuel costs
    100,124       100,124  
Other
    13,611       12,337  
TOTAL
    662,685       693,165  
                 
TOTAL ASSETS
  $ 5,982,437     $ 5,803,119  
                 
See Notes to Financial Statements.
               
 
 
ENTERGY GULF STATES LOUISIANA, L.L.C.
BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2013 and December 31, 2012
(Unaudited)
                 
      2013       2012  
   
(In Thousands)
 
                 
CURRENT LIABILITIES
               
Currently maturing long-term debt
  $ -     $ 75,000  
Accounts payable:
               
  Associated companies
    162,647       89,377  
  Other
    80,160       97,509  
Customer deposits
    51,348       48,265  
Taxes accrued
    -       21,021  
Accumulated deferred income taxes
    48,902       22,249  
Interest accrued
    30,739       25,437  
Deferred fuel costs
    -       948  
Pension and other postretirement liabilities
    8,120       7,803  
Gas hedge contracts
    1,261       2,620  
Other
    13,047       11,999  
TOTAL
    396,224       402,228  
                 
NON-CURRENT LIABILITIES
               
Accumulated deferred income taxes and taxes accrued
    1,463,685       1,403,195  
Accumulated deferred investment tax credits
    76,049       78,312  
Other regulatory liabilities
    143,209       103,444  
Decommissioning and asset retirement cost liabilities
    397,399       380,822  
Accumulated provisions
    37,025       97,230  
Pension and other postretirement liabilities
    420,780       416,220  
Long-term debt
    1,543,608       1,442,429  
Long-term payables - associated companies
    28,168       29,510  
Other
    91,381       66,725  
TOTAL
    4,201,304       4,017,887  
                 
Commitments and Contingencies
               
                 
EQUITY
               
Preferred membership interests without sinking fund
    10,000       10,000  
Member's equity
    1,437,258       1,438,233  
Accumulated other comprehensive loss
    (62,349 )     (65,229 )
TOTAL
    1,384,909       1,383,004  
                 
TOTAL LIABILITIES AND EQUITY
  $ 5,982,437     $ 5,803,119  
                 
See Notes to Financial Statements.
               
                 


 
STATEMENTS OF CHANGES IN EQUITY
For the Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
         
Common Equity
       
   
Preferred Membership Interests
   
Member's
Equity
   
Accumulated Other Comprehensive Income (Loss)
   
Total
 
   
(In Thousands)
 
                         
Balance at December 31, 2011
  $ 10,000     $ 1,393,386     $ (69,610 )   $ 1,333,776  
                                 
Net income
    -       128,958       -       128,958  
Member contribution
    -       1,000       -       1,000  
Other comprehensive income
    -       -       12,397       12,397  
Distributions declared on common equity
    -       (67,400 )     -       (67,400 )
Distributions declared on preferred membership interests
    -       (619 )     -       (619 )
Other
    -       (114 )     -       (114 )
                                 
Balance at September 30, 2012
  $ 10,000     $ 1,455,211     $ (57,213 )   $ 1,407,998  
                                 
                                 
Balance at December 31, 2012
  $ 10,000     $ 1,438,233     $ (65,229 )   $ 1,383,004  
                                 
Net income
    -       119,528       -       119,528  
Other comprehensive income
    -       -       2,880       2,880  
Distributions declared on common equity
    -       (119,900 )     -       (119,900 )
Distributions declared on preferred membership interests
    -       (619 )     -       (619 )
Other
    -       16       -       16  
                                 
Balance at September 30, 2013
  $ 10,000     $ 1,437,258     $ (62,349 )   $ 1,384,909  
                                 
See Notes to Financial Statements.
                               
                                 


 
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
                         
   
Three Months Ended
   
Increase/
       
Description
 
2013
   
2012
   
(Decrease)
   
%
 
   
(Dollars In Millions)
       
Electric Operating Revenues:
                       
  Residential
  $ 158     $ 119     $ 39       33  
  Commercial
    123       90       33       37  
  Industrial
    137       89       48       54  
  Governmental
    6       5       1       20  
    Total retail
    424       303       121       40  
  Sales for resale:
                               
     Associated companies
    102       103       (1 )     (1 )
     Non-associated companies
    11       9       2       22  
  Other
    12       11       1       9  
    Total
  $ 549     $ 426     $ 123       29  
                                 
Billed Electric Energy
                               
 Sales (GWh):
                               
  Residential
    1,740       1,718       22       1  
  Commercial
    1,514       1,500       14       1  
  Industrial
    2,337       2,210       127       6  
  Governmental
    59       61       (2 )     (3 )
    Total retail
    5,650       5,489       161       3  
  Sales for resale:
                               
     Associated companies
    1,940       2,295       (355 )     (15 )
     Non-associated companies
    245       229       16       7  
    Total
    7,835       8,013       (178 )     (2 )
                                 
                                 
   
Nine Months Ended
   
Increase/
         
Description
    2013       2012    
(Decrease)
   
%
 
   
(Dollars In Millions)
         
Electric Operating Revenues:
                               
  Residential
  $ 356     $ 295     $ 61       21  
  Commercial
    314       258       56       22  
  Industrial
    379       287       92       32  
  Governmental
    16       14       2       14  
    Total retail
    1,065       854       211       25  
  Sales for resale:
                               
     Associated companies
    283       281       2       1  
     Non-associated companies
    33       23       10       43  
  Other
    47       43       4       9  
    Total
  $ 1,428     $ 1,201     $ 227       19  
                                 
Billed Electric Energy
                               
 Sales (GWh):
                               
  Residential
    3,982       4,019       (37 )     (1 )
  Commercial
    3,923       4,003       (80 )     (2 )
  Industrial
    6,772       6,741       31       -  
  Governmental
    172       174       (2 )     (1 )
    Total retail
    14,849       14,937       (88 )     (1 )
  Sales for resale:
                               
     Associated companies
    4,858       5,858       (1,000 )     (17 )
     Non-associated companies
    642       673       (31 )     (5 )
    Total
    20,349       21,468       (1,119 )     (5 )
                                 


 
 
ENTERGY LOUISIANA, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS


Plan to Spin Off the Utility’s Transmission Business

See the “Plan to Spin Off the Utility’s Transmission Business” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K and herein for a discussion of Entergy’s plan to spin off its transmission business and merge it with a newly formed subsidiary of ITC Holdings Corp., including the planned retirement of debt and preferred securities.

Results of Operations

Net Income

Third Quarter 2013 Compared to Third Quarter 2012

Net income increased $20.4 million primarily due to higher net revenue and a lower effective income tax rate, partially offset by higher other operation and maintenance expenses, higher depreciation and amortization expenses, higher interest expense, and higher nuclear refueling outage expenses.

Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Net income decreased $36.9 million primarily due to the IRS tax settlement, in June 2012, related to the uncertain tax position regarding the Hurricane Katrina and Hurricane Rita Louisiana Act 55 financing, which resulted in a $142.7 million income tax benefit in 2012.  The prior year income tax benefit was partially offset by a $137.1 million ($84.3 million net-of-tax) regulatory charge, which reduced net revenue in 2012, because Entergy Louisiana is sharing the savings with customers.  Also contributing to the decrease in net income was higher other operation and maintenance expenses, higher depreciation and amortization expenses, and higher interest expense, partially offset by higher net revenue.  See Note 3 to the financial statements in the Form 10-K for additional discussion of the tax settlement and savings obligation.

Net Revenue

Third Quarter 2013 Compared to Third Quarter 2012

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory credits.  Following is an analysis of the change in net revenue comparing the third quarter 2013 to the third quarter 2012:

   
Amount
   
(In Millions)
     
2012 net revenue
 
$312.1 
Retail electric price
 
30.1 
Volume/weather
 
10.3 
Fuel recovery
 
5.0 
Net wholesale revenue
 
3.6 
Other
 
2.8 
2013 net revenue
 
$363.9 


 
126

Entergy Louisiana, LLC and Subsidiaries
Management’s Financial Discussion and Analysis


The retail electric price variance is primarily due to a formula rate plan increase effective January 2013.  See Note 2 to the financial statements herein and in the Form 10-K for more discussion of the formula rate plan increase.

The volume/weather variance is primarily due to increased usage during the unbilled sales period and increased billed electricity usage in the residential, commercial, and industrial sectors due to the effect of Hurricane Isaac, which decreased sales volume in 2012.  The increase in industrial usage was also driven by a prior year unplanned outage in the chemicals industry and a higher capacity factor in the petroleum industry.

The fuel recovery variance is primarily due to the expiration of the Evangeline gas contract on January 1, 2013.

The net wholesale revenue variance is primarily due to the sale to Entergy Gulf States Louisiana of one-third of Acadia Unit 2 capacity and energy.

Gross operating revenues and fuel and purchased power expenses

Gross operating revenues increased primarily due to:

·  
an increase of $128.9 million in fuel cost recovery revenues primarily due to higher fuel rates;
·  
the formula rate plan increase, as discussed above; and
·  
an increase of $10.8 million in affiliated sales as a result of the Acadia contract with Entergy Gulf States Louisiana effective January 2013.

Fuel and purchased power expenses increased primarily due to an increase in the average market prices of natural gas and purchased power and an increase in the recovery from customers of deferred fuel costs.

Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges (credits).  Following is an analysis of the change in net revenue comparing the nine months ended September 30, 2013 to the nine months ended September 30, 2012:

   
Amount
   
(In Millions)
     
2012 net revenue
 
$702.5 
Louisiana Act 55 financing savings obligation
 
139.1 
Retail electric price
 
63.8 
Net wholesale revenue
 
14.2 
Volume/weather
 
7.9 
Fuel recovery
 
6.3 
Other
 
1.0 
2013 net revenue
 
$934.8 

The Louisiana Act 55 financing savings obligation variance results from a regulatory charge recorded in the second quarter 2012 because Entergy Louisiana is sharing with customers the savings from an IRS settlement related to the uncertain tax position regarding the Hurricane Katrina and Hurricane Rita Louisiana Act 55 financing.  See Note 3 to the financial statements in the Form 10-K for additional discussion of the tax settlement and savings obligation.

The retail electric price variance is primarily due to a formula rate plan increase effective January 2013.  See Note 2 to the financial statements herein and in the Form 10-K for more discussion of the formula rate plan increase.
 
 
127

Entergy Louisiana, LLC and Subsidiaries
Management’s Financial Discussion and Analysis


The net wholesale revenue variance is primarily due to the sale to Entergy Gulf States Louisiana of one-third of Acadia Unit 2 capacity and energy.

The volume/weather variance is primarily due to increased usage during the unbilled sales period and increased billed electricity usage in all sectors due to the effect of Hurricane Isaac, which decreased sales volume in 2012.  The increase in industrial usage was also driven by a higher capacity factor in the petroleum industry.  The increase was partially offset by the effect of less favorable weather on residential and commercial sales as compared to the same period in prior year.

The fuel recovery variance is primarily due to the expiration of the Evangeline gas contract on January 1, 2013.

Gross operating revenues, fuel and purchased power expenses, and other regulatory charges (credits)

Gross operating revenues increased primarily due to:

·  
an increase of $291.2 million in fuel cost recovery revenues primarily due to higher fuel rates;
·  
the formula rate plan increase, as discussed above; and
·  
an increase of $21.8 million in affiliated sales as a result of the Acadia contract with Entergy Gulf States Louisiana effective January 2013.

Fuel and purchased power expenses increased primarily due to an increase in the average market prices of natural gas and purchased power and an increase in the recovery from customers of deferred fuel costs.

Other regulatory charges decreased primarily due to a regulatory charge recorded in the second quarter 2012 because Entergy Louisiana is sharing with customers the savings from an IRS settlement related to the uncertain tax position regarding the Hurricane Katrina and Hurricane Rita Louisiana Act 55 financing.  See Note 3 to the financial statements in the Form 10-K for additional discussion of the tax settlement and savings obligation.

Other Income Statement Variances

Third Quarter 2013 Compared to Third Quarter 2012

Nuclear refueling outage expenses increased primarily due to the amortization of higher expenses associated with the planned maintenance and refueling outage at Waterford 3.

Other operation and maintenance expenses increased primarily due to:

·  
an increase of $7.6 million in compensation and benefits costs primarily due to a decrease in the discount rates used to determine net periodic pension and other postretirement benefit costs and a settlement charge, recognized in September 2013, related to the payment of lump sum benefits out of the non-qualified pension plan.  See "MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates" in the Form 10-K and Note 6 to the financial statements herein for further discussion of benefits costs;
·  
an increase of $3.2 million in distribution expenses primarily due to higher labor and contract costs;
·  
an increase of $2.5 million in transmission expenses primarily due to higher equalization expenses, additional transmission services, and higher vegetation expenses; and
·  
an increase of $2.2 million as a result of lower write-offs of uncollectible accounts in 2012.

The increase was partially offset by a decrease of $4.3 million in fossil-fueled generation expenses due to an overall lower scope of work done during plant outages as compared to the prior year.



 
128

Entergy Louisiana, LLC and Subsidiaries
Management’s Financial Discussion and Analysis


Depreciation and amortization expenses increased primarily due to additions to plant in service, including the completion of the Waterford 3 steam generator replacement project in December 2012.

Interest expense increased primarily due to the following long-term debt issuances:

·  
$200 million of 3.30% Series first mortgage bonds in December 2012;
·  
$100 million of 4.70% Series first mortgage bonds in May 2013; and
·  
$325 million of 4.05% Series first mortgage bonds in August 2013.

Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Nuclear refueling outage expenses increased primarily due to the amortization of higher expenses associated with the planned maintenance and refueling outage at Waterford 3.

Other operation and maintenance expenses increased primarily due to:

·  
an increase of $13.9 million in compensation and benefits costs primarily due to a decrease in the discount rates used to determine net periodic pension and other postretirement benefit costs and a settlement charge, recognized in September 2013, related to the payment of lump sum benefits out of the non-qualified pension plan.  See "MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates" in the Form 10-K and Note 6 to the financial statements herein for further discussion of benefits costs;
·  
the prior year deferral, as approved by the LPSC and the FERC, of costs related to the transition and implementation of joining the MISO RTO, which reduced 2012 expenses by $5.2 million;
·  
an increase of $2.9 million in loss reserves; and
·  
an increase of $2.8 million in nuclear generation expenses primarily due to higher labor and materials costs.

The increase was partially offset by a decrease of $8.7 million in fossil-fueled generation expenses due to an overall lower scope of work done during plant outages as compared to the prior year and a decrease of $2.9 million in insurance expenses primarily due to decreases in premiums.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the completion of the Waterford 3 steam generator replacement project in December 2012.

Interest expense increased primarily due to the following long-term debt issuances:

·  
$200 million of 5.25% Series first mortgage bonds in July 2012;
·  
$200 million of 3.30% Series first mortgage bonds in December 2012;
·  
$100 million of 4.70% Series first mortgage bonds in May 2013; and
·  
$325 million of 4.05% Series first mortgage bonds in August 2013.

Income Taxes

The effective income tax rate was 28% for the third quarter 2013 and 25.8% for the nine months ended September 30, 2013.  The differences in the effective income tax rates for the third quarter 2013 and the nine months ended September 30, 2013 versus the federal statutory rate of 35% were due to 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, and the reversal of a portion of the provision for uncertain tax positions, partially offset by state income taxes.

The effective income tax rate was 34.7% for the third quarter 2012 and (110.1%) for the nine months ended September 30, 2012.  The difference in the effective income tax rate for the third quarter 2012 versus the federal statutory rate of 35% was due to a change in the regulatory treatment of state income taxes included in formula rate plan filings, partially offset by book and tax differences related to the non-taxable income distributions earned on preferred membership interests.  The difference in the effective income tax rate for the nine months ended September 30, 2012 versus the federal statutory rate of 35% was due to the reversal of the provision for uncertain tax positions related to the IRS
 
 
129

Entergy Louisiana, LLC and Subsidiaries
Management’s Financial Discussion and Analysis


settlement on how to treat the Louisiana Act 55 financing of the Hurricane Katrina and Hurricane Rita storm costs, book and tax differences related to the non-taxable income distributions earned on preferred membership interests, and book and tax differences related to the allowance for equity funds used during construction, partially offset by a change to the regulatory treatment of state income taxes included in formula rate plan filings.

Hurricane Isaac

See "MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Hurricane Isaac" in the Form 10-K for a discussion of Hurricane Isaac and the damage caused to Entergy Louisiana’s service area in August 2012.  In April 2013, Entergy Gulf States Louisiana and Entergy Louisiana filed a joint application with the LPSC relating to Hurricane Isaac system restoration costs.  Specifically, Entergy Louisiana requested that the LPSC determine the amount of such costs that were prudently incurred and are, thus, eligible for recovery from customers.  Including carrying costs and additional storm escrow funds, Entergy Louisiana is seeking determination that $247.7 million in system restoration costs were prudently incurred.  Entergy Louisiana intends to replenish its storm escrow accounts to $200 million primarily through traditional debt markets and has requested special rate treatment of any borrowings for that purpose.  In May 2013, Entergy Louisiana filed a supplemental application proposing a specific means to finance system restoration costs and related requests.  Entergy Louisiana is proposing to finance Hurricane Isaac restoration costs through Louisiana Act 55 financing, which was the same method it used for Hurricanes Katrina, Rita, Gustav, and Ike.

The LPSC Staff filed direct testimony in September 2013 concluding that Hurricane Isaac system restoration costs incurred by Entergy Gulf States Louisiana and Entergy Louisiana were reasonable and prudent, subject to proposed minor adjustments which totaled approximately 1% of each company’s costs.  The LPSC Staff also supported the requests to re-establish storm reserves of $90 million for Entergy Gulf States Louisiana and $200 million for Entergy Louisiana.  One intervenor filed testimony recommending storm reserve levels of $70 million for Entergy Gulf States Louisiana and $100 million for Entergy Louisiana, but takes no position on the prudence of the Hurricane Isaac system restoration costs.  An evidentiary hearing is scheduled in December 2013, with an LPSC decision expected in 2014.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2013 and 2012 were as follows:

   
2013
 
2012
   
(In Thousands)
         
Cash and cash equivalents at beginning of period
 
$30,086 
 
$878 
         
Cash flow provided by (used in):
       
 
Operating activities
 
450,443 
 
401,672 
 
Investing activities
 
(449,858)
 
(519,816)
 
Financing activities
 
10,221 
 
266,171 
Net increase in cash and cash equivalents
 
10,806 
 
148,027 
         
Cash and cash equivalents at end of period
 
$40,892 
 
$148,905 


 
130

Entergy Louisiana, LLC and Subsidiaries
Management’s Financial Discussion and Analysis


Operating Activities

Net cash flow provided by operating activities increased $48.8 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to the increased recovery of fuel costs due to an increase in the amount of deferred fuel to be recovered compared to last year, decreased Hurricane Isaac storm spending in 2013, and a decrease of $15.5 million in pension contributions.  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.

Investing Activities

Net cash flow used in investing activities decreased $70 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to:

·  
receipts of $187 million from the storm reserve escrow account in 2013, compared to receipts of $13.7 million in 2012;
·  
a decrease in nuclear construction expenditures due to the Waterford 3 steam generator replacement project in 2012;
·  
a decrease 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; and
·  
a decrease in distribution construction expenditures due to higher Hurricane Isaac spending in prior year.

The decrease was offset by an increase in fossil-fueled generation construction expenditures due to spending on the Ninemile Unit 6 self-build project, an increase in transmission construction expenditures as a result of additional reliability work performed in 2013, and money pool activity.

Increases in Entergy Louisiana’s receivable from the money pool are a use of cash flow, and Entergy Louisiana’s receivable from the money pool increased by $42.4 million for the nine months ended September 30, 2013 compared to increasing by $30.7 million for the nine months ended September 30, 2012.  The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Financing Activities

Net cash flow provided by financing activities decreased $256 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to an increase of $350.7 million in common equity dividends paid in 2013 and the net issuance of $397 million of long-term debt in 2013 compared to the net issuance of $428.3 million of long-term debt in 2012.  The decrease was partially offset by money pool activity.  See Note 5 to the financial statements in the Form 10-K and Note 4 herein for more details of long-term debt.

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 $118.4 million for the nine months ended September 30, 2012.

Capital Structure

Entergy Louisiana’s capitalization is balanced between equity and debt, as shown in the following table.  The increase in the debt to capital ratio for Entergy Louisiana as of September 30, 2013 is primarily due to an increase in long-term debt as a result of the issuance of $100 million of 4.70% Series first mortgage bonds in May 2013 and $325 million of 4.05% Series first mortgage bonds in August 2013.

 
131

Entergy Louisiana, LLC and Subsidiaries
Management’s Financial Discussion and Analysis




   
September 30,
2013
 
December 31,
2012
         
Debt to capital
 
52.8% 
 
48.4% 
Effect of excluding securitization bonds
 
(1.3%)
 
(1.6%)
Debt to capital, excluding securitization bonds (a)
 
51.5% 
 
46.8% 
Effect of subtracting cash
 
(0.4%) 
 
(0.3%)
Net debt to net capital, excluding securitization bonds (a)
 
51.1% 
 
46.5% 

(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 and long-term debt, including the currently maturing portion.  Capital consists of debt and member’s 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 is developing its capital investment plan for 2014 through 2016 and currently anticipates making $1.3 billion in capital investments during that period.  In addition to routine capital spending to maintain operations, the capital investment plan includes specific investments and initiatives such as the Ninemile Point Unit 6 self-build project, NRC post-Fukushima requirements, and transmission spending to support economic development projects, reliability, and new compliance projects.

Entergy Louisiana obtained short-term borrowing authorization from the FERC under which it may borrow through October 2015, up to the aggregate amount, at any one time outstanding, of $250 million.  See Note 4 to the financial statements for further discussion of Entergy Louisiana’s short-term borrowing limits.  Entergy Louisiana has also obtained an order from the FERC authorizing long-term securities issuances through October 2015.  Entergy Louisiana has also obtained long-term financing authorization from the FERC that extends through October 2015 for issuances by its nuclear fuel company variable interest entity.

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

September 30,
2013
 
December 31,
2012
 
September 30,
2012
 
December 31,
2011
(In Thousands)
             
$51,867
 
$9,433
 
$30,710
 
($118,415)

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

In May 2013, Entergy Louisiana issued $100 million of 4.70% Series first mortgage bonds due June 2063. Entergy Louisiana used the proceeds for general corporate purposes.
 
 
132

Entergy Louisiana, LLC and Subsidiaries
Management’s Financial Discussion and Analysis


In August 2013, Entergy Louisiana issued $325 million of 4.05% Series first mortgage bonds due September 2023. Entergy Louisiana used the proceeds to repay borrowings under its $200 million credit facility and for general corporate purposes.

Entergy Louisiana has a credit facility in the amount of $200 million scheduled to expire in March 2018.  No borrowings were outstanding under the facility as of September 30, 2013.  See Note 4 to the financial statements herein for additional discussion of the credit facility.

The Entergy Louisiana nuclear fuel company variable interest entity has a credit facility in the amount of $90 million scheduled to expire in June 2016.  As of September 30, 2013, $24.3 million in letters of credit were outstanding under the credit facility to support a like amount of commercial paper issued by the Entergy Louisiana nuclear fuel company variable interest entity.  See Note 4 to the financial statements for additional discussion of the nuclear fuel company variable interest entity credit facility.

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.  Following are updates to that discussion.

Retail Rates

In November 2011 the LPSC approved a one-year extension of Entergy Louisiana’s formula rate plan.  In May 2012, Entergy Louisiana made its formula rate plan filing with the LPSC for the 2011 test year.  The filing reflected a 9.63% earned return on common equity, which is within the earnings bandwidth and results in no cost of service rate change under the formula rate plan.  The filing also reflected an $18.1 million rate increase for incremental capacity costs.  In August 2012, Entergy Louisiana submitted a revised filing that reflects an earned return on common equity of 10.38%, which is still within the earnings bandwidth, resulting in no cost of service rate change.  The revised filing also indicates that an increase of $15.9 million should be reflected in the incremental capacity rider.  The rate change was implemented, subject to refund, effective for bills rendered the first billing cycle of September 2012.  Subsequently, in December 2012, Entergy Louisiana submitted a revised evaluation report that reflects two items: 1) a $17 million reduction for the first-year capacity charges for the purchase by Entergy Gulf States Louisiana from Entergy Louisiana of one-third of Acadia Unit 2 capacity and energy, and 2) an $88 million increase for the first-year retail revenue requirement associated with the Waterford 3 replacement steam generator project, which was in-service in December 2012.  These rate changes were implemented, subject to refund, effective with the first billing cycle of January 2013.  In April 2013, Entergy Louisiana and the LPSC staff filed a joint report resolving the 2011 test year formula rate plan and recovery related to the Grand Gulf uprate.  This report was approved by the LPSC in April 2013.  With completion of the Waterford 3 replacement steam generator project, the LPSC is conducting a prudence review in connection with a filing made by Entergy Louisiana in April 2013 with regard to the following aspects of the replacement project: 1) project management; 2) cost controls; 3) success in achieving stated objectives; 4) the costs of the replacement project; and 5) the outage length and replacement power costs.  A procedural schedule for the prudence review has not yet been established.

See Note 2 to the financial statements in the Form 10-K for a discussion of the base rate case filed by Entergy Louisiana with the LPSC in February 2013.  In April 2013 the LPSC established a procedural schedule providing for hearings in December 2013, with a decision by the LPSC expected in 2014.  On July 26, 2013, with the concurrence of Entergy Louisiana based upon an expected 60-day delay of the procedural schedule, the ALJ suspended the procedural schedule pending resolution of the appeal by Entergy Gulf States Louisiana, Entergy Louisiana and the LPSC staff regarding the ALJ’s denial of a motion to consolidate the rate cases of Entergy Gulf States Louisiana and Entergy Louisiana.  At an August 2013 meeting the LPSC rejected the proposed consolidation.  A new procedural schedule was established calling for an evidentiary hearing in December 2013.  Entergy Louisiana submitted an opposed motion to modify the procedural schedule to allow for settlement negotiations, which are ongoing.  The motion was granted and the evidentiary hearing has been rescheduled to occur in January 2014.
 
 
133

Entergy Louisiana, LLC and Subsidiaries
Management’s Financial Discussion and Analysis


In March 2013, Entergy Louisiana filed a rate case for the Algiers area, which is in New Orleans and is regulated by the City Council.  Entergy Louisiana is requesting a rate increase of $13 million over three years, including a 10.4% return on common equity and a formula rate plan mechanism identical to its LPSC request.  Hearings are scheduled for April 2014.  New rates are currently expected to become effective in second quarter 2014.

Fuel and Purchased Power Cost Recovery

In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings.  The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by Entergy Louisiana for the period from 2005 through 2009.  The LPSC Staff issued its audit report in January 2013.  The LPSC staff recommended that Entergy Louisiana refund approximately $1.9 million, plus interest, to customers and realign the recovery of approximately $1 million from Entergy Louisiana’s fuel adjustment clause to base rates.  The recommended refund was made by Entergy Louisiana in May 2013 in the form of a credit to customers through its fuel adjustment clause filing.  Two parties have intervened in the proceeding.  A procedural schedule has been established for the identification of issues by the intervenors and for Entergy Louisiana to submit comments regarding the LPSC Staff report and any issues raised by intervenors.  One intervenor is seeking further proceedings regarding certain issues it raised in its comments on the LPSC Staff report.  Entergy Louisiana has filed responses to both the LPSC Staff report and the issues raised by the intervenor.  As required by the procedural schedule, a joint status report was submitted in October 2013 by the parties.  That report requests that a status conference be convened by the ALJ to address open issues, including whether further proceedings will be required.  A status conference has been scheduled for December 5, 2013.

Federal Regulation

See “System Agreement” and “Entergy’s Proposal to Join MISO” in the “Rate, Cost-recovery, and Other Regulation – Federal Regulation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for updates to the Federal Regulation discussion in the Form 10-K.

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, unbilled revenue, and qualified pension and other postretirement benefits.



 

CONSOLIDATED INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
   
Three Months Ended
   
Nine Months Ended
 
   
2013
   
2012
   
2013
   
2012
 
   
(In Thousands)
   
(In Thousands)
 
                         
OPERATING REVENUES
                       
Electric
  $ 782,789     $ 614,044     $ 2,024,679     $ 1,658,189  
                                 
OPERATING EXPENSES
                               
Operation and Maintenance:
                               
   Fuel, fuel-related expenses, and
                               
     gas purchased for resale
    206,329       134,108       418,188       320,991  
   Purchased power
    213,832       168,817       679,254       505,935  
   Nuclear refueling outage expenses
    9,317       6,103       25,248       18,573  
   Other operation and maintenance
    123,344       106,523       355,696       334,559  
Decommissioning
    5,437       5,169       16,106       18,172  
Taxes other than income taxes
    19,337       17,913       57,124       52,122  
Depreciation and amortization
    60,664       54,642       181,409       162,474  
Other regulatory charges (credits) - net
    (1,318 )     (956 )     (7,612 )     128,749  
TOTAL
    636,942       492,319       1,725,413       1,541,575  
                                 
OPERATING INCOME
    145,847       121,725       299,266       116,614  
                                 
OTHER INCOME
                               
Allowance for equity funds used during construction
    8,854       9,981       21,693       27,032  
Interest and investment income
    21,149       21,566       64,064       63,178  
Miscellaneous - net
    (618 )     519       (2,271 )     (1,680 )
TOTAL
    29,385       32,066       83,486       88,530  
                                 
INTEREST EXPENSE
                               
Interest expense
    39,206       35,731       112,539       101,434  
Allowance for borrowed funds used during construction
    (3,714 )     (4,776 )     (9,198 )     (12,530 )
TOTAL
    35,492       30,955       103,341       88,904  
                                 
INCOME BEFORE INCOME TAXES
    139,740       122,836       279,411       116,240  
                                 
Income taxes
    39,143       42,628       72,061       (127,977 )
                                 
NET INCOME
    100,597       80,208       207,350       244,217  
                                 
Preferred dividend requirements and other
    1,738       1,738       5,213       5,213  
                                 
EARNINGS APPLICABLE TO
                               
COMMON EQUITY
  $ 98,859     $ 78,470     $ 202,137     $ 239,004  
                                 
See Notes to Financial Statements.
                               
                                 


  
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
 
 
Three Months Ended
   
Nine Months Ended
 
   
2013
   
2012
   
2013
   
2012
 
   
(In Thousands)
   
(In Thousands)
 
                         
Net Income
  $ 100,597     $ 80,208     $ 207,350     $ 244,217  
Other comprehensive income
                               
   Pension and other postretirement liabilities
                               
         (net of tax expense of $542, $493, $1,631, and $1,480)
    684       630       2,045       1,890  
         Other comprehensive income
    684       630       2,045       1,890  
Comprehensive Income
  $ 101,281     $ 80,838     $ 209,395     $ 246,107  
                                 
                                 
See Notes to Financial Statements.
                               


 
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2013 and 2012
(Unaudited)
             
   
2013
   
2012
 
   
(In Thousands)
 
             
OPERATING ACTIVITIES
           
Net income
  $ 207,350     $ 244,217  
Adjustments to reconcile net income to net cash flow provided by operating activities:
         
  Depreciation, amortization, and decommissioning, including nuclear fuel amortization
    250,232       299,745  
  Deferred income taxes, investment tax credits, and non-current taxes accrued
    168,988       (94,765 )
  Changes in working capital:
               
    Receivables
    (131,198 )     (37,610 )
    Fuel inventory
    992       (3 )
    Accounts payable
    (39,947 )     65,772  
    Prepaid taxes and taxes accrued
    (37,490 )     6,383  
    Interest accrued
    1,527       (1,557 )
    Deferred fuel costs
    22,450       (30,132 )
    Other working capital accounts
    21,742       (29,490 )
Changes in provisions for estimated losses
    (187,642 )     (17,392 )
Changes in other regulatory assets
    (19,483 )     (42,781 )
Changes in other regulatory liabilities
    146,329       139,624  
Changes in pension and other postretirement liabilities
    1,851       (17,361 )
Other
    44,742       (82,978 )
Net cash flow provided by operating activities
    450,443       401,672  
                 
INVESTING ACTIVITIES
               
Construction expenditures
    (583,451 )     (429,820 )
Allowance for equity funds used during construction
    21,693       27,032  
Nuclear fuel purchases
    (41,209 )     (134,413 )
Proceeds from the sale of nuclear fuel
    23,438       48,990  
Receipts from storm reserve escrow account
    187,007       13,669  
Remittances to transition charge account
    (14,844 )     (22,113 )
Payments from transition charge account
    8,759       15,472  
Proceeds from nuclear decommissioning trust fund sales
    12,211       19,833  
Investment in nuclear decommissioning trust funds
    (21,006 )     (28,422 )
Changes in money pool receivable - net
    (42,434 )     (30,710 )
Other
    (22 )     666  
Net cash flow used in investing activities
    (449,858 )     (519,816 )
                 
FINANCING ACTIVITIES
               
Proceeds from the issuance of long-term debt
    418,009       465,997  
Retirement of long-term debt
    (20,960 )     (37,649 )
Changes in credit borrowings - net
    (30,361 )     (37,949 )
Change in money pool payable - net
    -       (118,415 )
Distributions paid:
               
  Common equity
    (351,254 )     (600 )
  Preferred membership interests
    (5,213 )     (5,213 )
Net cash flow provided by financing activities
    10,221       266,171  
                 
Net increase in cash and cash equivalents
    10,806       148,027  
                 
Cash and cash equivalents at beginning of period
    30,086       878  
                 
Cash and cash equivalents at end of period
  $ 40,892     $ 148,905  
                 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
               
Cash paid (received) during the period for:
               
  Interest - net of amount capitalized
  $ 106,975     $ 98,979  
  Income taxes
  $ (3,874 )   $ (3,601 )
                 
                 
See Notes to Financial Statements.
               


 
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2013 and December 31, 2012
(Unaudited)
             
   
2013
   
2012
 
   
(In Thousands)
 
             
CURRENT ASSETS
           
Cash and cash equivalents:
           
  Cash
  $ 350     $ 814  
  Temporary cash investments
    40,542       29,272  
    Total cash and cash equivalents
    40,892       30,086  
Securitization recovery trust account
    10,467       4,382  
Accounts receivable:
               
  Customer
    182,711       86,072  
  Allowance for doubtful accounts
    (1,413 )     (867 )
  Associated companies
    98,222       42,938  
  Other
    9,022       9,354  
  Accrued unbilled revenues
    101,941       79,354  
    Total accounts receivable
    390,483       216,851  
Accumulated deferred income taxes
    103,399       113,319  
Deferred fuel costs
    4,118       26,568  
Fuel inventory
    22,591       23,583  
Materials and supplies - at average cost
    154,104       152,170  
Deferred nuclear refueling outage costs
    22,349       44,457  
Prepaid taxes
    45,427       7,937  
Prepayments and other
    11,926       12,129  
TOTAL
    805,756       631,482  
                 
OTHER PROPERTY AND INVESTMENTS
               
Investment in affiliate preferred membership interests
    807,423       807,423  
Decommissioning trust funds
    325,443       287,418  
Storm reserve escrow account
    -       186,985  
Non-utility property - at cost (less accumulated depreciation)
    442       578  
TOTAL
    1,133,308       1,282,404  
                 
UTILITY PLANT
               
Electric
    8,699,613       8,603,319  
Property under capital lease
    324,440       324,440  
Construction work in progress
    647,527       404,714  
Nuclear fuel
    170,203       204,019  
TOTAL UTILITY PLANT
    9,841,783       9,536,492  
Less - accumulated depreciation and amortization
    3,720,317       3,590,146  
UTILITY PLANT - NET
    6,121,466       5,946,346  
                 
DEFERRED DEBITS AND OTHER ASSETS
               
Regulatory assets:
               
  Regulatory asset for income taxes - net
    310,672       193,114  
  Other regulatory assets (includes securitization property of
               
     $160,690 as of September 30, 2013 and
               
     $172,838 as of December 31, 2012)
    815,487       913,562  
  Deferred fuel costs
    67,998       67,998  
Other
    45,677       39,178  
TOTAL
    1,239,834       1,213,852  
                 
TOTAL ASSETS
  $ 9,300,364     $ 9,074,084  
                 
See Notes to Financial Statements.
               
 
 
ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2013 and December 31, 2012
 (Unaudited)
                 
      2013       2012  
   
(In Thousands)
 
                 
CURRENT LIABILITIES
               
Currently maturing long-term debt
  $ 70,231     $ 14,236  
Short-term borrowings
    24,296       54,657  
Accounts payable:
               
  Associated companies
    90,733       103,454  
  Other
    127,342       266,904  
Customer deposits
    89,375       88,805  
Accumulated deferred income taxes
    3,865       -  
Interest accrued
    38,791       37,264  
Pension and other postretirement liabilities
    9,421       9,170  
Gas hedge contracts
    1,408       3,442  
Other
    16,211       13,382  
TOTAL
    471,673       591,314  
                 
NON-CURRENT LIABILITIES
               
Accumulated deferred income taxes and taxes accrued
    1,112,480       930,606  
Accumulated deferred investment tax credits
    68,059       70,193  
Other regulatory liabilities
    523,130       376,801  
Decommissioning
    434,228       418,122  
Accumulated provisions
    8,832       196,474  
Pension and other postretirement liabilities
    541,303       539,703  
Long-term debt (includes securitization bonds of
               
  $174,844 as of September 30, 2013 and
               
  $181,553 as of December 31, 2012)
    3,159,085       2,811,859  
Other
    78,751       68,516  
TOTAL
    5,925,868       5,412,274  
                 
Commitments and Contingencies
               
                 
EQUITY
               
Preferred membership interests without sinking fund
    100,000       100,000  
Member's equity
    2,846,910       3,016,628  
Accumulated other comprehensive loss
    (44,087 )     (46,132 )
TOTAL
    2,902,823       3,070,496  
                 
TOTAL LIABILITIES AND EQUITY
  $ 9,300,364     $ 9,074,084  
                 
See Notes to Financial Statements.
               
                 


 
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
         
Common Equity
       
   
Preferred Membership Interests
   
Member's
Equity
   
Accumulated Other Comprehensive Income (Loss)
   
Total
 
     
(In Thousands)
       
                         
Balance at December 31, 2011
  $ 100,000     $ 2,504,436     $ (39,507 )   $ 2,564,929  
                                 
Net income
    -       244,217       -       244,217  
Other comprehensive income
    -       -       1,890       1,890  
Distributions to parent
    -       (600 )     -       (600 )
Distributions declared on preferred membership interests
    -       (5,213 )     -       (5,213 )
                                 
Balance at September 30, 2012
  $ 100,000     $ 2,742,840     $ (37,617 )   $ 2,805,223  
                                 
Balance at December 31, 2012
  $ 100,000     $ 3,016,628     $ (46,132 )   $ 3,070,496  
                                 
Net income
    -       207,350       -       207,350  
Other comprehensive income
    -       -       2,045       2,045  
Distributions to parent
    -       (371,855 )     -       (371,855 )
Distributions declared on preferred membership interests
    -       (5,213 )     -       (5,213 )
                                 
Balance at September 30, 2013
  $ 100,000     $ 2,846,910     $ (44,087 )   $ 2,902,823  
                                 
See Notes to Financial Statements.
                               
                                 

 

SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
                         
   
Three Months Ended
   
Increase/
       
Description
 
2013
   
2012
   
(Decrease)
   
%
 
   
(Dollars In Millions)
       
Electric Operating Revenues:
                       
  Residential
  $ 286     $ 227     $ 59       26  
  Commercial
    174       136       38       28  
  Industrial
    255       180       75       42  
  Governmental
    12       11       1       9  
    Total retail
    727       554       173       31  
  Sales for resale:
                               
     Associated companies
    34       46       (12 )     (26 )
     Non-associated companies
    1       1       -       -  
  Other
    21       13       8       62  
    Total
  $ 783     $ 614     $ 169       28  
                                 
Billed Electric Energy
                               
 Sales (GWh):
                               
  Residential
    2,884       2,866       18       1  
  Commercial
    1,820       1,786       34       2  
  Industrial
    4,275       4,157       118       3  
  Governmental
    126       125       1       1  
    Total retail
    9,105       8,934       171       2  
  Sales for resale:
                               
     Associated companies
    705       682       23       3  
     Non-associated companies
    9       21       (12 )     (57 )
    Total
    9,819       9,637       182       2  
                                 
                                 
   
Nine Months Ended
   
Increase/
         
Description
    2013       2012    
(Decrease)
   
%
 
   
(Dollars In Millions)
         
Electric Operating Revenues:
                               
  Residential
  $ 651     $ 541     $ 110       20  
  Commercial
    444       368       76       21  
  Industrial
    734       554       180       32  
  Governmental
    35       29       6       21  
    Total retail
    1,864       1,492       372       25  
  Sales for resale:
                               
     Associated companies
    84       99       (15 )     (15 )
     Non-associated companies
    1       1       -       -  
  Other
    76       66       10       15  
    Total
  $ 2,025     $ 1,658     $ 367       22  
                                 
Billed Electric Energy
                               
 Sales (GWh):
                               
  Residential
    6,767       6,844       (77 )     (1 )
  Commercial
    4,641       4,675       (34 )     (1 )
  Industrial
    12,687       12,448       239       2  
  Governmental
    373       362       11       3  
    Total retail
    24,468       24,329       139       1  
  Sales for resale:
                               
     Associated companies
    1,322       1,749       (427 )     (24 )
     Non-associated companies
    26       39       (13 )     (33 )
    Total
    25,816       26,117       (301 )     (1 )
                                 
 
 
 
 
ENTERGY MISSISSIPPI, INC.

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS


Plan to Spin Off the Utility’s Transmission Business

See the “Plan to Spin Off the Utility’s Transmission Business” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K and herein for a discussion of Entergy’s plan to spin off its transmission business and merge it with a newly formed subsidiary of ITC Holdings Corp., including the planned retirement of debt and preferred securities.

Results of Operations

Net Income

Third Quarter 2013 Compared to Third Quarter 2012

Net income increased $6.7 million primarily due to higher net revenue.

Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Net income increased $15 million primarily due to higher net revenue, partially offset by higher other operation and maintenance expenses.

Net Revenue

Third Quarter 2013 Compared to Third Quarter 2012

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges.  Following is an analysis of the change in net revenue comparing the third quarter 2013 to the third quarter 2012:

   
Amount
   
(In Millions)
     
2012 net revenue
 
$167.9 
Retail electric price
 
11.5 
Reserve equalization
 
2.9 
Volume/weather
 
(2.8)
Other
 
1.9 
2013 net revenue
 
$181.4 

The retail electric price variance is primarily due to the recovery of Hinds plant costs through the power management rider, as approved by the MPSC, effective with the first billing cycle of 2013.  The net income effect of the Hinds plant cost recovery is limited to a portion representing an allowed return on equity on the net plant investment with the remainder offset by the Hinds plant costs in other operation and maintenance expenses, depreciation expenses, and taxes other than income taxes.  The increase is partially offset by a temporary increase in 2012 in the storm cost recovery rider, as approved by the MPSC for a five-month period effective August 2012.  The increase in revenues in 2012 was offset by costs included in other operation and maintenance expenses and had no effect on net income.

 
142

Entergy Mississippi, Inc.
Management’s Financial Discussion and Analysis



The reserve equalization variance is primarily due to increased reserve equalization revenue resulting from the acquisition of the Hinds plant in November 2012.

The volume/weather variance is primarily due to the effect of less favorable weather on residential and commercial sales in the third quarter 2013 as compared to the same period in the prior year and decreased electricity usage in the third quarter 2013 as compared to the same period in the prior year.  Billed electricity usage decreased 166 GWh, or 4%, across all customer classes.

Gross operating revenues and fuel and purchased power expenses

Gross operating revenues increased primarily due to:

·  
an increase of $29.3 million in fuel cost recovery revenues primarily due to higher fuel rates;
·  
an increase of $24.1 million in gross wholesale revenues due to an increase in sales to affiliated customers;
·  
an increase of $16.9 million in power management rider revenue, as approved by the MPSC, primarily resulting from the acquisition of the Hinds plant in November 2012, as discussed previously; and
·  
an increase of $10.7 million in rider revenue primarily due to an increase in the Grand Gulf rider effective October 2012.

Fuel and purchased power expenses increased primarily due to:

·  
an increase in the average market price of natural gas;
·  
an increase in deferred fuel expenses as a result of higher fuel revenues primarily due to lower 2012 fuel rates as a result of bandwidth remedy payments refunded to customers in August and September 2012.  See Note 2 to the financial statements herein and in the Form 10-K for a discussion of the System Agreement proceedings; and
·  
an increase in Grand Gulf capacity costs as a result of the Grand Gulf uprate.

Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory credits.  Following is an analysis of the change in net revenue comparing the nine months ended September 30, 2013 to the nine months ended September 30, 2012:

   
Amount
   
(In Millions)
     
2012 net revenue
 
$432.4 
Retail electric price
 
45.0 
Reserve equalization
 
10.3 
Volume/weather
 
(3.9)
Other
 
2.7 
2013 net revenue
 
$486.5 

The retail electric price variance is primarily due to the recovery of Hinds plant costs through the power management rider, as approved by the MPSC, effective with the first billing cycle of 2013.  The net income effect of the Hinds plant cost recovery is limited to a portion representing an allowed return on equity on the net plant investment with the remainder offset by the Hinds plant costs in other operation and maintenance expenses, depreciation expenses, and taxes other than income taxes.  The increase is partially offset by a temporary increase in 2012 in the storm cost recovery rider, as approved by the MPSC for a five-month period effective August 2012.  The increase in revenues in 2012 was offset by costs included in other operation and maintenance expenses and had no effect on net income.
 
 
143

Entergy Mississippi, Inc.
Management’s Financial Discussion and Analysis


The reserve equalization variance is primarily due to increased reserve equalization revenue resulting from the acquisition of the Hinds plant in November 2012.

The volume/weather variance is primarily due to decreased electricity usage in the nine months ended September 30, 2013 as compared to the same period in the prior year.  The decrease in industrial usage is primarily due to the petroleum and primary metals industries.  Billed electricity usage decreased 336 GWh, or 3%, across all customer classes.

Gross operating revenues and fuel and purchased power expenses

Gross operating revenues increased primarily due to:

·  
an increase of $64.1 million in gross wholesale revenues due to an increase in sales to affiliated customers;
·  
an increase of $45.2 million in power management rider revenue, as approved by the MPSC, primarily resulting from the acquisition of the Hinds plant in November 2012, as discussed previously;
·  
an increase of $29.8 million in rider revenue primarily due to an increase in the Grand Gulf rider effective October 2012; and
·  
an increase of $19.4 million in fuel cost recovery revenues primarily due to higher fuel rates.

Fuel and purchased power expenses increased primarily due to an increase in Grand Gulf capacity costs as a result of the Grand Gulf uprate and an increase in the average market price of natural gas.

Other Income Statement Variances

Third Quarter 2013 Compared to Third Quarter 2012

Other operation and maintenance expenses decreased primarily due to a temporary increase in 2012 of $10.2 million in storm damage accruals, as approved by the MPSC for a five-month period effective August 2012, substantially offset by an increase of $4.6 million in fossil-fueled generation expenses primarily due to the acquisition of the Hinds plant in November 2012 and an increase of $2.6 million in compensation and benefits costs primarily due to a decrease in the discount rates used to determine net periodic pension and other postretirement benefit costs and a settlement charge, recognized in September 2013, related to the payment of lump sum benefits out of the non-qualified pension plan.  See "MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates" in the Form 10-K and Note 6 to the financial statements herein for further discussion of benefits costs.

Taxes other than income taxes increased primarily due to an increase in ad valorem taxes as a result of a higher assessment in 2013 primarily due to the acquisition of the Hinds plant in November 2012.

Depreciation and amortization expenses increased primarily due to an increase in plant in service, including the acquisition of the Hinds plant in November 2012.

Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Other operation and maintenance expenses increased primarily due to an increase of $26.1 million in fossil-fueled generation expenses resulting from a higher scope of work done during plant outages in 2013 as compared to the same period in 2012 and the acquisition of the Hinds plant in November 2012. The increase was partially offset by a temporary increase in 2012 of $10.2 million in storm damage accruals, as approved by the MPSC for a five-month period effective August 2012.

Taxes other than income taxes increased primarily due to an increase in ad valorem taxes as a result of a higher assessment in 2013 primarily due to the acquisition of the Hinds plant in November 2012.

Depreciation and amortization expenses increased primarily due to an increase in plant in service, including the acquisition of the Hinds plant in November 2012.
 
 
144

Entergy Mississippi, Inc.
Management’s Financial Discussion and Analysis


Income Taxes

The effective income tax rate was 39.3% for the third quarter 2013 and 39.6% for the nine months ended September 30, 2013.  The differences in the effective income tax rates for the third quarter 2013 and the nine months ended September 30, 2013 versus the federal statutory rate of 35% were primarily due to state income taxes and certain book and tax differences related to utility plant items.

The effective income tax rate was 40.6% for the third quarter 2012 and 41.8% for the nine months ended September 30, 2012.  The differences in the effective income tax rates for the third quarter 2012 and the nine months ended September 30, 2012 versus the federal statutory rate of 35% were primarily due to state income taxes.

Baxter Wilson Plant Event

On September 11, 2013, Entergy Mississippi’s Baxter Wilson (Unit 1) power plant experienced a significant unplanned outage event.  The cause of the event is currently under investigation.  Entergy Mississippi is still in the process of assessing the nature and extent of the damage to the unit. The current estimate of costs to return the unit to service, however, is in the range of $25 million to $30 million.  This estimate and return to service schedule may change as restorative activities occur.  The costs necessary to return the plant to service are expected to be incurred during the fourth quarter 2013 through the second quarter 2014.  Entergy Mississippi believes that the damage is covered by its property insurance policy, subject to a $20 million deductible.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2013 and 2012 were as follows:

   
2013
 
2012
   
(In Thousands)
         
Cash and cash equivalents at beginning of period
 
$52,970 
 
$16 
         
Cash flow provided by (used in):
       
 
Operating activities
 
147,847 
 
156,020 
 
Investing activities
 
(109,269)
 
(124,165)
 
Financing activities
 
(90,457)
 
(4,214)
Net increase (decrease) in cash and cash equivalents
 
(51,879)
 
27,641 
         
Cash and cash equivalents at end of period
 
$1,091 
 
$27,657 

Operating Activities

Net cash provided by operating activities decreased $8.2 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to a decrease in the recovery of fuel costs and the receipt of System Agreement bandwidth remedy payments of $33 million in January 2012 to implement the FERC’s remedy in an October 2011 order for the period June-December 2005, of which approximately $13 million had been refunded to customers as of September 30, 2012.  The decrease was partially offset by a decrease of $4.6 million in pension contributions.  See Note 2 to the financial statements herein and in the Form 10-K for a discussion of the System Agreement proceedings.  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.
 
 
145

Entergy Mississippi, Inc.
Management’s Financial Discussion and Analysis


Investing Activities

Net cash used in investing activities decreased $14.9 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to money pool activity and decreased distribution construction expenditures as a result of spending on Hurricane Isaac in 2012.  The decrease was partially offset by an increase in transmission construction expenditures due to more reliability work in 2013 as compared to 2012 and an increase in fossil-fueled generation construction expenditures as a result of an increased scope of work during outages in 2013 as compared to 2012.

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 $16.9 million for the nine months ended September 30, 2013 compared to increasing by $5.5 million for the nine months ended September 30, 2012.  The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Financing Activities

Net cash used in financing activities increased $86.2 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to the payment at maturity of $100 million of 5.15% Series first mortgage bonds in February 2013, partially offset by money pool activity. See Note 4 to the financial statements herein for a discussion of long-term debt and credit facilities.

Increases in Entergy Mississippi’s payable to the money pool are a source of cash flow, and Entergy Mississippi’s payable to the money pool increased by $19.2 million for the nine months ended September 30, 2013 compared to decreasing by $2 million for the nine months ended September 30, 2012.

Capital Structure

Entergy Mississippi’s capitalization is balanced between equity and debt, as shown in the following table.  The decrease in the debt to capital ratio is due to the retirement of $100 million of 5.15% Series first mortgage bonds in February 2013.

   
September 30,
2013
 
December 31,
2012
         
Debt to capital
 
52.1% 
 
55.9% 
Effect of subtracting cash
 
-% 
 
(1.2%)
Net debt to net capital
 
52.1% 
 
54.7% 

Net debt consists of debt less cash and cash equivalents.  Debt consists of short-term borrowings, capital lease obligations, and long-term debt, including the currently maturing portion.  Capital consists of debt, preferred stock without sinking fund, and common equity.  Net capital consists of capital less cash and cash equivalents.  Entergy 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 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 is developing its capital investment plan for 2014 through 2016 and currently anticipates making $658 million in capital investments during that period.  In addition to routine capital spending to maintain operations, the capital investment plan includes specific investments and initiatives such as transmission spending to support economic development projects, reliability, and new compliance projects.
 
 
146

Entergy Mississippi, Inc.
Management’s Financial Discussion and Analysis



Entergy Mississippi has obtained short-term borrowing authorization from the FERC under which it may borrow through October 2015, up to the aggregate amount, at any one time outstanding, of $175 million.  See Note 4 to the financial statements for further discussion of Entergy Mississippi’s short-term borrowing limits.  Entergy Mississippi has also obtained an order from the FERC authorizing long-term securities issuances through October 2015.

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

September 30,
2013
 
December 31,
2012
 
September 30,
2012
 
December 31,
2011
(In Thousands)
             
($19,150)
 
$16,878
 
$5,497
 
($1,999)

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

In May 2013, Entergy Mississippi renewed its three separate credit facilities through May 2014 and increased the aggregate amount available under these credit facilities to $92.5 million. No borrowings were outstanding under the credit facilities as of September 30, 2013.  See Note 4 to the financial statements herein for additional discussion of the credit facilities.

In February 2013, Entergy Mississippi redeemed, at maturity, its $100 million 5.15% Series first mortgage bonds.

In October 2013, Entergy Mississippi redeemed, prior to maturity, its $16.03 million 4.60% Series pollution control revenue bonds due April 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 the formula rate plan and fuel and purchased power cost recovery. Following are updates to that discussion.

Formula Rate Plan

In March 2013, Entergy Mississippi submitted its formula rate plan 2012 test year filing.  The filing requested a $36.3 million revenue increase to reset Entergy Mississippi's return on common equity to 10.55%, which is a point within the formula rate plan bandwidth.  In June 2013, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation, in which both parties agreed that the MPSC should approve a $22.3 million rate increase for Entergy Mississippi which, with other adjustments reflected in the stipulation, would have the effect of resetting Entergy Mississippi’s return on common equity to 10.59% when adjusted for performance under the formula rate plan.  In August 2013 the MPSC approved the joint stipulation between Entergy Mississippi and the Mississippi Public Utilities Staff authorizing the rate increase effective with September 2013 bills.  Additionally, the MPSC authorized Entergy Mississippi to defer approximately $1.2 million in MISO-related implementation costs incurred in 2012, along with other MISO-related implementation costs to be incurred in 2013.
 
 
147

Entergy Mississippi, Inc.
Management’s Financial Discussion and Analysis



In August 2012 the MPSC opened inquiries to review whether the current formulaic methodology used to calculate the return on common equity in both Entergy Mississippi’s formula rate plan and Mississippi Power Company’s annual formula rate plan is still appropriate or can be improved to better serve the public interest. The intent of this inquiry and review is for informational purposes only; the evaluation of any recommendations for changes to the existing methodology would take place in a general rate case or in the existing formula rate plan docket.  In March 2013 the Staff filed its consultant’s report which noted the return on common equity estimation methods used by Entergy Mississippi and Mississippi Power Company are commonly used throughout the electric utility industry.  The report suggested ways in which the methods used by Entergy Mississippi and Mississippi Power Company might be improved, but did not recommend specific changes in the return on common equity formulas or calculations at this time.

Storm Damage Accrual and Storm Cost Recovery

On July 1, 2013, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation, wherein both parties agreed that approximately $32 million in storm restoration costs incurred in 2011 and 2012 were prudently incurred and chargeable to the storm damage reserve, while approximately $700,000 in prudently incurred costs were more properly recoverable through the formula rate plan.  Entergy Mississippi and the Mississippi Public Utilities Staff also agreed that the storm damage accrual should be increased from $750,000 per month to $1.75 million per month.  In September 2013 the MPSC approved the joint stipulation with the increase in the storm damage accrual effective with October 2013 bills.

Federal Regulation

See “System Agreement” and “Entergy’s Proposal to Join MISO” in the “Rate, Cost-recovery, and Other Regulation – Federal Regulation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for updates to the Federal Regulation discussion in the Form 10-K.

Nuclear Matters

See “Nuclear Matters” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis 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 unbilled revenue and qualified pension and other postretirement benefits.




INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
   
Three Months Ended
   
Nine Months Ended
 
   
2013
   
2012
   
2013
   
2012
 
   
(In Thousands)
   
(In Thousands)
 
                         
OPERATING REVENUES
                       
Electric
  $ 397,833     $ 321,771     $ 1,015,513     $ 860,735  
                                 
OPERATING EXPENSES
                               
Operation and Maintenance:
                               
   Fuel, fuel-related expenses, and
                               
     gas purchased for resale
    118,688       57,230       263,437       204,703  
   Purchased power
    97,709       93,817       275,783       232,140  
   Other operation and maintenance
    62,263       64,446       189,822       173,043  
Taxes other than income taxes
    21,208       19,742       61,322       56,980  
Depreciation and amortization
    27,717       24,377       81,268       72,451  
Other regulatory charges (credits) - net
    62       2,828       (10,237 )     (8,476 )
TOTAL
    327,647       262,440       861,395       730,841  
                                 
OPERATING INCOME
    70,186       59,331       154,118       129,894  
                                 
OTHER INCOME
                               
Allowance for equity funds used during construction
    371       760       1,817       2,950  
Interest and investment income
    239       19       565       43  
Miscellaneous - net
    (767 )     (806 )     (2,601 )     (2,916 )
TOTAL
    (157 )     (27 )     (219 )     77  
                                 
INTEREST EXPENSE
                               
Interest expense
    14,585       14,113       44,753       42,761  
Allowance for borrowed funds used during construction
    (307 )     (405 )     (1,233 )     (1,568 )
TOTAL
    14,278       13,708       43,520       41,193  
                                 
INCOME BEFORE INCOME TAXES
    55,751       45,596       110,379       88,778  
                                 
Income taxes
    21,938       18,516       43,678       37,102  
                                 
NET INCOME
    33,813       27,080       66,701       51,676  
                                 
Preferred dividend requirements and other
    707       707       2,121       2,121  
                                 
EARNINGS APPLICABLE TO
                               
COMMON STOCK
  $ 33,106     $ 26,373     $ 64,580     $ 49,555  
                                 
See Notes to Financial Statements.
                               


 
 
 
 
 
 
 
 
 
 
 
 
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STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2013 and 2012
(Unaudited)
             
   
2013
   
2012
 
   
(In Thousands)
 
             
OPERATING ACTIVITIES
           
Net income
  $ 66,701     $ 51,676  
Adjustments to reconcile net income to net cash flow provided by operating activities:
 
  Depreciation and amortization
    81,268       72,451  
  Deferred income taxes, investment tax credits, and non-current taxes accrued
    36,845       39,703  
  Changes in assets and liabilities:
               
    Receivables
    (50,692 )     23,552  
    Fuel inventory
    5,249       (3,377 )
    Accounts payable
    17,940       12,637  
    Taxes accrued
    (11,345 )     (15,150 )
    Interest accrued
    1,960       (3,683 )
    Deferred fuel costs
    (10,179 )     (12,249 )
    Other working capital accounts
    2,069       (10,977 )
    Provisions for estimated losses
    (232 )     (2,496 )
    Other regulatory assets
    8,153       10,526  
    Pension and other postretirement liabilities
    (5,444 )     (10,438 )
    Other assets and liabilities
    5,554       3,845  
Net cash flow provided by operating activities
    147,847       156,020  
                 
INVESTING ACTIVITIES
               
Construction expenditures
    (128,006 )     (121,634 )
Allowance for equity funds used during construction
    1,817       2,950  
Change in money pool receivable - net
    16,878       (5,497 )
Other
    42       16  
Net cash flow used in investing activities
    (109,269 )     (124,165 )
                 
FINANCING ACTIVITIES
               
Retirement of long-term debt
    (100,000 )     -  
Change in money pool payable - net
    19,150       (1,999 )
Dividends paid:
               
  Common stock
    (7,400 )     -  
  Preferred stock
    (2,121 )     (2,121 )
Other
    (86 )     (94 )
Net cash flow used in financing activities
    (90,457 )     (4,214 )
                 
Net increase (decrease) in cash and cash equivalents
    (51,879 )     27,641  
                 
Cash and cash equivalents at beginning of period
    52,970       16  
                 
Cash and cash equivalents at end of period
  $ 1,091     $ 27,657  
                 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
         
Cash paid during the period for:
               
  Interest - net of amount capitalized
  $ 40,718     $ 44,481  
  Income taxes
  $ 1,999     $ 2,118  
                 
See Notes to Financial Statements.
               


 
BALANCE SHEETS
ASSETS
September 30, 2013 and December 31, 2012
(Unaudited)
             
   
2013
   
2012
 
   
(In Thousands)
 
             
CURRENT ASSETS
           
Cash and cash equivalents:
           
  Cash
  $ 1,082     $ 585  
  Temporary cash investments
    9       52,385  
    Total cash and cash equivalents
    1,091       52,970  
Accounts receivable:
               
  Customer
    89,316       49,836  
  Allowance for doubtful accounts
    (1,071 )     (910 )
  Associated companies
    17,201       25,504  
  Other
    7,330       11,072  
  Accrued unbilled revenues
    49,585       43,045  
    Total accounts receivable
    162,361       128,547  
Deferred fuel costs
    36,669       26,490  
Accumulated deferred income taxes
    2,084       44,027  
Fuel inventory - at average cost
    43,529       48,778  
Materials and supplies - at average cost
    40,101       40,331  
Prepayments and other
    4,712       5,329  
TOTAL
    290,547       346,472  
                 
OTHER PROPERTY AND INVESTMENTS
               
Non-utility property - at cost (less accumulated depreciation)
    4,677       4,698  
Escrow accounts
    61,794       61,836  
TOTAL
    66,471       66,534  
                 
UTILITY PLANT
               
Electric
    3,800,355       3,708,743  
Property under capital lease
    6,038       8,112  
Construction work in progress
    75,900       62,876  
TOTAL UTILITY PLANT
    3,882,293       3,779,731  
Less - accumulated depreciation and amortization
    1,390,608       1,324,627  
UTILITY PLANT - NET
    2,491,685       2,455,104  
                 
DEFERRED DEBITS AND OTHER ASSETS
               
Regulatory assets:
               
  Regulatory asset for income taxes - net
    61,238       63,614  
  Other regulatory assets
    395,694       401,471  
Other
    19,579       20,832  
TOTAL
    476,511       485,917  
                 
TOTAL ASSETS
  $ 3,325,214     $ 3,354,027  
                 
See Notes to Financial Statements.
               
 
 
ENTERGY MISSISSIPPI, INC.
BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2013 and December 31, 2012
(Unaudited)
                 
      2013       2012  
   
(In Thousands)
 
 
 
CURRENT LIABILITIES
               
Currently maturing long-term debt
  $ -     $ 100,000  
Short-term borrowings
    17       21  
Accounts payable:
               
  Associated companies
    67,981       42,377  
  Other
    51,063       44,856  
Customer deposits
    73,266       71,182  
Taxes accrued
    40,982       52,327  
Accumulated deferred income taxes
    3,333       218  
Interest accrued
    20,186       18,226  
Other
    29,401       21,490  
TOTAL
    286,229       350,697  
                 
NON-CURRENT LIABILITIES
               
Accumulated deferred income taxes and taxes accrued
    754,316       761,812  
Accumulated deferred investment tax credits
    8,220       7,257  
Obligations under capital lease
    4,479       5,329  
Other regulatory liabilities
    1,647       1,235  
Asset retirement cost liabilities
    6,309       6,039  
Accumulated provisions
    35,588       35,820  
Pension and other postretirement liabilities
    155,422       160,866  
Long-term debt
    1,069,627       1,069,519  
Other
    16,170       25,426  
TOTAL
    2,051,778       2,073,303  
                 
Commitments and Contingencies
               
                 
Preferred stock without sinking fund
    50,381       50,381  
                 
COMMON EQUITY
               
Common stock, no par value, authorized 12,000,000
               
  shares; issued and outstanding 8,666,357 shares in 2013 and 2012
    199,326       199,326  
Capital stock expense and other
    (690 )     (690 )
Retained earnings
    738,190       681,010  
TOTAL
    936,826       879,646  
                 
TOTAL LIABILITIES AND EQUITY
  $ 3,325,214     $ 3,354,027  
                 
See Notes to Financial Statements.
               


 
STATEMENTS OF CHANGES IN COMMON EQUITY
For the Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
   
Common Equity
       
   
Common
Stock
   
Capital Stock Expense and
Other
   
Retained
Earnings
   
Total
 
   
(In Thousands)
 
                         
Balance at December 31, 2011
  $ 199,326     $ (690 )   $ 637,070     $ 835,706  
                                 
Net income
    -       -       51,676       51,676  
Preferred stock dividends
    -       -       (2,121 )     (2,121 )
                                 
Balance at September 30, 2012
  $ 199,326     $ (690 )   $ 686,625     $ 885,261  
                                 
                                 
Balance at December 31, 2012
  $ 199,326     $ (690 )   $ 681,010     $ 879,646  
                                 
Net income
    -       -       66,701       66,701  
Common stock dividends
    -       -       (7,400 )     (7,400 )
Preferred stock dividends
    -       -       (2,121 )     (2,121 )
                                 
Balance at September 30, 2013
  $ 199,326     $ (690 )   $ 738,190     $ 936,826  
                                 
See Notes to Financial Statements.
                               

 

 
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
                         
   
Three Months Ended
   
Increase/
       
Description
 
2013
   
2012
   
(Decrease)
   
%
 
   
(Dollars In Millions)
       
Electric Operating Revenues:
                       
  Residential
  $ 167     $ 144     $ 23       16  
  Commercial
    126       108       18       17  
  Industrial
    43       36       7       19  
  Governmental
    11       10       1       10  
    Total retail
    347       298       49       16  
  Sales for resale:
                               
     Associated companies
    30       5       25       500  
     Non-associated companies
    7       7       -       -  
  Other
    14       12       2       17  
    Total
  $ 398     $ 322     $ 76       24  
                                 
Billed Electric Energy
                               
 Sales (GWh):
                               
  Residential
    1,836       1,917       (81 )     (4 )
  Commercial
    1,424       1,468       (44 )     (3 )
  Industrial
    612       651       (39 )     (6 )
  Governmental
    115       117       (2 )     (2 )
    Total retail
    3,987       4,153       (166 )     (4 )
  Sales for resale:
                               
     Associated companies
    527       54       473       876  
     Non-associated companies
    92       109       (17 )     (16 )
    Total
    4,606       4,316       290       7  
                                 
                                 
   
Nine Months Ended
   
Increase/
         
Description
    2013       2012    
(Decrease)
   
%
 
   
(Dollars In Millions)
         
Electric Operating Revenues:
                               
  Residential
  $ 401     $ 355     $ 46       13  
  Commercial
    321       292       29       10  
  Industrial
    115       107       8       7  
  Governmental
    31       28       3       11  
    Total retail
    868       782       86       11  
  Sales for resale:
                               
     Associated companies
    79       15       64       427  
     Non-associated companies
    18       18       -       -  
  Other
    51       46       5       11  
    Total
  $ 1,016     $ 861     $ 155       18  
                                 
Billed Electric Energy
                               
 Sales (GWh):
                               
  Residential
    4,345       4,387       (42 )     (1 )
  Commercial
    3,623       3,785       (162 )     (4 )
  Industrial
    1,675       1,801       (126 )     (7 )
  Governmental
    305       311       (6 )     (2 )
    Total retail
    9,948       10,284       (336 )     (3 )
  Sales for resale:
                               
     Associated companies
    1,302       153       1,149       751  
     Non-associated companies
    211       201       10       5  
    Total
    11,461       10,638       823       8  
                                 

 
 
 
ENTERGY NEW ORLEANS, INC.

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS


Plan to Spin Off the Utility’s Transmission Business

See the “Plan to Spin Off the Utility’s Transmission Business” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K and herein for a discussion of Entergy’s plan to spin off its transmission business and merge it with a newly formed subsidiary of ITC Holdings Corp., including the planned retirement of debt and preferred securities.

Results of Operations

Net Income

Third Quarter 2013 Compared to Third Quarter 2012

Net income decreased $2.5 million primarily due to higher other operation and maintenance expenses and higher taxes other than income taxes, partially offset by higher net revenue.

Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Net income decreased $7.8 million primarily due to higher other operation and maintenance expenses, higher taxes other than income taxes, and higher interest expense, partially offset by higher net revenue.

Net Revenue

Third Quarter 2013 Compared to Third Quarter 2012

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges.  Following is an analysis of the changes in net revenue comparing the third quarter 2013 to the third quarter 2012:

   
Amount
   
(In Millions)
     
2012 net revenue
 
$69.4 
Volume/weather
 
1.3 
Rider revenue
 
1.2 
Other
 
0.6 
2013 net revenue
 
$72.5 

The volume/weather variance is primarily due to an increase of 57 GWh, or 5%, in billed electricity usage in the residential and commercial sectors due to the effect of Hurricane Isaac, which decreased sales volume in 2012, and in part to a 2% increase in the average number of both residential and commercial customers.

The rider revenue variance is primarily due to an increase in franchise tax rider revenue as a result of higher retail revenues.  There is a corresponding increase in taxes other than income taxes, resulting in no effect on net income.


 
156

Entergy New Orleans, Inc.
Management’s Financial Discussion and Analysis


Gross operating revenues and fuel expenses

Gross operating revenues increased primarily due to an increase of $17.4 million in electric fuel cost recovery revenues due to higher fuel rates.  Entergy New Orleans’s fuel and purchased power recovery mechanism is discussed in Note 2 to the financial statements in the Form 10-K.

Fuel expenses increased primarily due to an increase in deferred fuel expense as a result of higher fuel revenues, an increase in the market price of natural gas, and an increase in gas purchased for resale as a result of an increase in price and volume.

Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges.  Following is an analysis of the changes in net revenue comparing the nine months ended September 30, 2013 to the nine months ended September 30, 2012:

   
Amount
   
(In Millions)
     
2012 net revenue
 
$185.9 
Rider revenue
 
2.4 
Net gas revenue
 
2.3 
Volume/weather
 
1.9 
Retail electric price
 
(1.5)
Other
 
0.5 
2013 net revenue
 
$191.5 

The rider revenue variance is primarily due to an increase in franchise tax rider revenue as a result of higher retail revenues.  There is a corresponding increase in taxes other than income taxes, resulting in no effect on net income.

The net gas revenue variance is primarily due to the effect of more favorable weather primarily in the residential and commercial sectors in 2013 as compared to the same period in prior year.

The volume/weather variance is primarily due to an increase of 64 GWh, or 5%, in weather-adjusted usage in the residential sector due to the effect of Hurricane Isaac, which decreased sales volume in 2012, and in part to a 2% increase in the average number of residential customers, partially offset by less favorable weather in 2013 as compared to the same period in prior year.

The retail electric price variance is primarily due to an additional provision recorded in 2013 as a result of a settlement relating to the formula rate plan proceeding.  See Note 2 to the financial statements for additional discussion of the settlement.

Gross operating revenues and fuel and purchased power expenses

Gross operating revenues increased primarily due to an increase of $40 million in electric fuel cost recovery revenues due to higher fuel rates and an increase of $8.9 million in gas fuel cost recovery revenues due to higher fuel rates.  Entergy New Orleans’s fuel and purchased power recovery mechanism is discussed in Note 2 to the financial statements in the Form 10-K.

Fuel and purchased power expenses increased primarily due to an increase in Grand Gulf capacity and energy purchases as a result of the Grand Gulf uprate and an increase in deferred fuel expense as a result of higher fuel revenues.
 
 
 
157

Entergy New Orleans, Inc.
Management’s Financial Discussion and Analysis


Other Income Statement Variances

Third Quarter 2013 Compared to Third Quarter 2012

Other operation and maintenance expenses increased primarily due to:

·  
an increase of $2.1 million in compensation and benefits costs primarily due to a decrease in the discount rates used to determine net periodic pension and other postretirement benefit costs and a settlement charge recognized in September 2013 related to the payment of lump sum benefits out of the non-qualified pension plan.  See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for further discussion of benefits costs; and
·  
an increase of $1.5 million in fossil-fueled generation expenses due to an overall higher scope of work done during plant outages as compared to prior year.

Taxes other than income taxes increased primarily due to an increase in local franchise taxes resulting from higher electric and gas retail revenues as compared to prior year and an increase in ad valorem taxes resulting from higher assessments.  Franchise taxes have no effect on net income as these taxes are recovered through the franchise tax rider.

Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Other operation and maintenance expenses increased primarily due to:

·  
an increase of $8.5 million in fossil-fueled generation expenses due to an overall higher scope of work done during plant outages as compared to prior year; and
·  
an increase of $1.9 million in compensation and benefits costs primarily due to a decrease in the discount rates used to determine net periodic pension and other postretirement benefit costs and a settlement charge recognized in September 2013 related to the payment of lump sum benefits out of the non-qualified pension plan.  See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for further discussion of benefits costs.

The increase was partially offset by a decrease of $1.5 million due to expenses recorded in 2012 related to the Energy Smart Program.

Taxes other than income taxes increased primarily due to an increase in local franchise taxes resulting from higher electric and gas retail revenues as compared to prior year and an increase in ad valorem taxes resulting from higher assessments.  Franchise taxes have no effect on net income as these taxes are recovered through the franchise tax rider.

Interest expense increased primarily due to the issuance of $30 million of 5.00% Series first mortgage bonds in November 2012 and the issuance of $100 million of 3.90% Series first mortgage bonds in June 2013, partially offset by the retirement, at maturity, of $70 million of 5.25% Series first mortgage bonds in August 2013.

Income Taxes

The effective income tax rate was 34.4% for the third quarter 2013 and 26.7% for the nine months ended September 30, 2013.  The difference in the effective income tax rate for the third quarter 2013 versus the federal statutory rate of 35% was primarily due to flow-through tax accounting, offset by certain book and tax differences related to utility plant items and state income taxes.  The difference in the effective income tax rate for the nine months ended September 30, 2013 versus the federal statutory rate of 35% was primarily due to flow-through tax accounting and book and tax differences related to the allowance for equity funds used during construction, partially offset by certain book and tax differences related to utility plant items and state income taxes.
 
 
158

Entergy New Orleans, Inc.
Management’s Financial Discussion and Analysis


The effective income tax rate was 36.9% for the third quarter 2012 and 26.1% for the nine months ended September 30, 2012.  The difference in the effective income tax rate for the third quarter 2012 versus the federal statutory rate of 35% was due to state income taxes and certain book and tax differences related to utility plant items, partially offset by flow-through tax accounting.  The difference in the effective income tax rate for the nine months ended September 30, 2012 versus the federal statutory rate of 35% was due to the provision for uncertain tax positions and flow-through tax accounting, offset by certain book and tax differences related to utility plant items and state income taxes.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2013 and 2012 were as follows:

   
2013
 
2012
   
(In Thousands)
         
Cash and cash equivalents at beginning of period
 
$9,391 
 
$9,834 
         
Cash flow provided by (used in):
       
 
Operating activities
 
59,948 
 
23,160 
 
Investing activities
 
(81,546)
 
(44,538)
 
Financing activities
 
27,710 
 
12,716 
Net increase (decrease) in cash and cash equivalents
 
6,112 
 
(8,662)
         
Cash and cash equivalents at end of period
 
$15,503 
 
$1,172 

Operating Activities

Net cash flow provided by operating activities increased $36.8 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to the increased recovery of fuel costs, System Agreement bandwidth remedy payments of $15 million received in 2013, and a $3.2 million decrease in pension contributions.  See Note 2 to the financial statements herein and in the Form 10-K for a discussion of the System Agreement proceedings.  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.

Investing Activities

Net cash flow used in investing activities increased $37 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to:

·  
money pool activity;
·  
an increase in fossil-fueled generation construction expenditures due to an increased scope of work in 2013; and
·  
an increase in transmission construction expenditures as a result of additional reliability work performed in 2013.

The increase was partially offset by a decrease in distribution construction expenditures due to higher spending related to Hurricane Isaac in 2012 and net receipts from the storm reserve escrow account of $1.9 million for the nine months ended September 30, 2013 compared to net payments to the storm reserve escrow account of $6.8 million for the nine months ended September 30, 2012.


 
159

Entergy New Orleans, Inc.
Management’s Financial Discussion and Analysis


Increases in Entergy New Orleans’s receivable from the money pool are a use of cash flow, and Entergy New Orleans’s receivable from the money pool increased $15.5 million for the nine months ended September 30, 2013 compared to decreasing $9.1 million for the nine months ended September 30, 2012.  The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Financing Activities

Net cash provided by financing activities increased $15 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to the issuance of $100 million of 3.90% Series first mortgage bonds in June 2013, partially offset by the retirement of $70 million of 5.25% Series first mortgage bonds in August 2013 and money pool activity.

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 by $15.7 million for the nine months ended September 30, 2012.

Capital Structure

Entergy New Orleans’s capitalization is balanced between equity and debt, as shown in the following table.  The increase in debt to capital ratio is due to the net issuance of $30 million of first mortgage bonds in 2013, as discussed above.

   
September 30,
 2013
 
December 31,
2012
         
Debt to capital
 
50.1% 
 
47.7% 
Effect of subtracting cash
 
(1.7%)
 
(1.2%)
Net debt to net capital
 
48.4% 
 
46.5% 

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, preferred stock without sinking fund, and common equity.  Net capital consists of capital less cash and cash equivalents.  Entergy New Orleans 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 New Orleans’s financial condition.  Entergy New Orleans uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy New Orleans’s financial condition 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 is developing its capital investment plan for 2014 through 2016 and currently anticipates making $284 million in capital investments during that period.  In addition to routine capital spending to maintain operations, the capital investment plan includes specific investments and initiatives such as transmission spending to support economic development projects, reliability, and new compliance projects.

Entergy New Orleans has obtained short-term borrowing authorization from the FERC under which it may borrow through October 2015, up to the aggregate amount, at any one time outstanding, of $100 million.  See Note 4 to the financial statements for further discussion of Entergy New Orleans’s short-term borrowing limits.  The long-term securities issuances of Entergy New Orleans are limited to amounts authorized by the City Council, and the current authorization extends through July 2014.

 
160

Entergy New Orleans, Inc.
Management’s Financial Discussion and Analysis


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

September 30,
2013
 
December 31,
2012
 
September 30,
2012
 
December 31,
2011
(In Thousands)
             
$18,403
 
$2,923
 
($15,719)
 
$9,074

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 November 2013.  No borrowings were outstanding under the facility as of September 30, 2013.  In October 2013, Entergy New Orleans renewed its credit facility through November 2014.  See Note 4 to the financial statements herein for additional discussion of the credit facility.

In June 2013, Entergy New Orleans issued $100 million of 3.90% Series first mortgage bonds due July 2023.  Entergy New Orleans used the proceeds to pay, at maturity, its $70 million 5.25% Series first mortgage bonds due August 2013 and for general corporate purposes.

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.

As discussed in the Form 10-K, in May 2012, Entergy New Orleans filed its electric and gas formula rate plan evaluation reports for the 2011 test year.   In August 2013 the City Council unanimously approved a settlement of all issues in the formula rate plan proceeding.  Pursuant to the terms of the settlement, Entergy New Orleans  implemented an approximately $1.625 million net decrease to the electric rates that were in effect prior to the electric rate increase implemented in October 2012, with no change in gas rates.  Entergy New Orleans is in the process of refunding to customers approximately $6.0 million over the four-month period from September 2013 through December 2013 to make the electric rate decrease effective as of the first billing cycle of October 2012.  Entergy New Orleans had previously recorded provisions for the majority of the refund to customers, but recorded an additional $1.1 million provision in second quarter 2013 as a result of the settlement.

Federal Regulation

See “System Agreement” and “Entergy’s Proposal to Join MISO” in the “Rate, Cost-recovery, and Other Regulation – Federal Regulation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for updates to the Federal Regulation discussion in the Form 10-K.

Nuclear Matters

See “Nuclear Matters” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis 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 New Orleans’s accounting for unbilled revenue and qualified pension and other postretirement benefits.




INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
   
Three Months Ended
   
Nine Months Ended
 
   
2013
   
2012
   
2013
   
2012
 
   
(In Thousands)
   
(In Thousands)
 
                         
OPERATING REVENUES
                       
Electric
  $ 161,737     $ 146,459     $ 397,126     $ 360,772  
Natural gas
    16,904       15,106       70,822       59,193  
TOTAL
    178,641       161,565       467,948       419,965  
                                 
OPERATING EXPENSES
                               
Operation and Maintenance:
                               
   Fuel, fuel-related expenses, and
                               
     gas purchased for resale
    42,207       29,298       83,656       68,585  
   Purchased power
    63,705       62,410       192,028       164,042  
   Other operation and maintenance
    33,820       28,671       102,187       92,475  
Taxes other than income taxes
    13,373       11,941       37,141       33,110  
Depreciation and amortization
    9,392       9,178       28,394       27,446  
Other regulatory charges - net
    249       502       748       1,483  
TOTAL
    162,746       142,000       444,154       387,141  
                                 
OPERATING INCOME
    15,895       19,565       23,794       32,824  
                                 
OTHER INCOME
                               
Allowance for equity funds used during construction
    223       185       656       487  
Interest and investment income
    24       8       68       29  
Miscellaneous - net
    (277 )     (385 )     (921 )     (1,147 )
TOTAL
    (30 )     (192 )     (197 )     (631 )
                                 
INTEREST EXPENSE
                               
Interest expense
    3,661       2,738       10,312       8,366  
Allowance for borrowed funds used during construction
    (130 )     (88 )     (351 )     (230 )
TOTAL
    3,531       2,650       9,961       8,136  
                                 
INCOME BEFORE INCOME TAXES
    12,334       16,723       13,636       24,057  
                                 
Income taxes
    4,248       6,168       3,646       6,276  
                                 
NET INCOME
    8,086       10,555       9,990       17,781  
                                 
Preferred dividend requirements and other
    241       241       724       724  
                                 
EARNINGS APPLICABLE TO
                               
COMMON STOCK
  $ 7,845     $ 10,314     $ 9,266     $ 17,057  
                                 
See Notes to Financial Statements.
                               


 
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2013 and 2012
(Unaudited)
   
2013
   
2012
 
   
(In Thousands)
 
OPERATING ACTIVITIES
           
Net income
  $ 9,990     $ 17,781  
Adjustments to reconcile net income to net cash flow provided by operating activities:
         
  Depreciation and amortization
    28,394       27,446  
  Deferred income taxes, investment tax credits, and non-current taxes accrued
    (13,649 )     12,269  
  Changes in assets and liabilities:
               
    Receivables
    (944 )     (17,721 )
    Fuel inventory
    (1,769 )     1,977  
    Accounts payable
    1,628       11,175  
    Prepaid taxes and taxes accrued
    4,502       (10,826 )
    Interest accrued
    (266 )     (740 )
    Deferred fuel costs
    19,108       (6,095 )
    Other working capital accounts
    (9,813 )     (6,628 )
    Provisions for estimated losses
    (1,871 )     6,015  
    Other regulatory assets
    13,915       (10,748 )
    Pension and other postretirement liabilities
    (2,581 )     (6,597 )
    Other assets and liabilities
    13,304       5,852  
Net cash flow provided by operating activities
    59,948       23,160  
                 
INVESTING ACTIVITIES
               
Construction expenditures
    (68,643 )     (47,325 )
Allowance for equity funds used during construction
    656       487  
Change in money pool receivable - net
    (15,480 )     9,074  
Receipts from storm reserve escrow account
    7,749       -  
Payments to storm reserve escrow account
    (5,828 )     (6,774 )
Net cash flow used in investing activities
    (81,546 )     (44,538 )
                 
FINANCING ACTIVITIES
               
Proceeds from the issuance of long-term debt
    98,495       -  
Retirement of long-term debt
    (70,061 )     -  
Change in money pool payable - net
    -       15,719  
Dividends paid:
               
  Common stock
    -       (1,700 )
  Preferred stock
    (724 )     (724 )
Other
    -       (579 )
Net cash flow provided by financing activities
    27,710       12,716  
                 
Net increase (decrease) in cash and cash equivalents
    6,112       (8,662 )
                 
Cash and cash equivalents at beginning of period
    9,391       9,834  
                 
Cash and cash equivalents at end of period
  $ 15,503     $ 1,172  
                 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
               
Cash paid during the period for:
               
  Interest - net of amount capitalized
  $ 9,775     $ 8,431  
  Income taxes
  $ 425     $ -  
                 
See Notes to Financial Statements.
               

 

 
BALANCE SHEETS
ASSETS
September 30, 2013 and December 31, 2012
(Unaudited)
             
   
2013
   
2012
 
   
(In Thousands)
 
             
CURRENT ASSETS
           
Cash and cash equivalents
           
  Cash
  $ 1,117     $ 319  
  Temporary cash investments
    14,386       9,072  
        Total cash and cash equivalents
    15,503       9,391  
Accounts receivable:
               
  Customer
    47,901       33,142  
  Allowance for doubtful accounts
    (573 )     (446 )
  Associated companies
    31,592       29,326  
  Other
    2,357       3,115  
  Accrued unbilled revenues
    18,408       18,124  
    Total accounts receivable
    99,685       83,261  
Accumulated deferred income taxes
    6,257       9,517  
Fuel inventory - at average cost
    3,546       1,777  
Materials and supplies - at average cost
    11,242       10,889  
Prepaid taxes
    -       1,377  
Prepayments and other
    6,404       3,201  
TOTAL
    142,637       119,413  
                 
OTHER PROPERTY AND INVESTMENTS
               
Non-utility property at cost (less accumulated depreciation)
    1,016       1,016  
Storm reserve escrow account
    8,684       10,605  
TOTAL
    9,700       11,621  
                 
UTILITY PLANT
               
Electric
    878,648       860,358  
Natural gas
    219,529       217,769  
Construction work in progress
    26,572       11,135  
TOTAL UTILITY PLANT
    1,124,749       1,089,262  
Less - accumulated depreciation and amortization
    560,085       549,587  
UTILITY PLANT - NET
    564,664       539,675  
                 
DEFERRED DEBITS AND OTHER ASSETS
               
Regulatory assets:
               
  Deferred fuel costs
    4,080       4,080  
  Other regulatory assets
    188,088       202,003  
Other
    6,690       4,997  
TOTAL
    198,858       211,080  
                 
TOTAL ASSETS
  $ 915,859     $ 881,789  
                 
See Notes to Financial Statements.
               
 
 
 
ENTERGY NEW ORLEANS, INC.
BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2013 and December 31, 2012
(Unaudited)
                 
      2013       2012  
   
(In Thousands)
 
                 
CURRENT LIABILITIES
               
Currently maturing long-term debt
  $ -     $ 70,000  
Accounts payable:
               
  Associated companies
    32,646       28,778  
  Other
    26,742       31,209  
Customer deposits
    22,422       21,974  
Taxes accrued
    3,125       -  
Interest accrued
    2,754       3,020  
Deferred fuel costs
    21,265       2,157  
System agreement cost equalization
    6,256       16,880  
Other
    7,398       3,479  
TOTAL CURRENT LIABILITIES
    122,608       177,497  
                 
NON-CURRENT LIABILITIES
               
Accumulated deferred income taxes and taxes accrued
    172,340       172,790  
Accumulated deferred investment tax credits
    1,136       1,300  
Regulatory liability for income taxes - net
    8,417       24,291  
Other regulatory liabilities
    23,867       11,060  
Asset retirement cost liabilities
    2,307       2,193  
Accumulated provisions
    13,160       15,031  
Pension and other postretirement liabilities
    81,209       83,790  
Long-term debt
    225,942       126,300  
Gas system rebuild insurance proceeds
    34,820       44,207  
Other
    5,442       7,985  
TOTAL NON-CURRENT LIABILITIES
    568,640       488,947  
                 
                 
Commitments and Contingencies
               
                 
Preferred stock without sinking fund
    19,780       19,780  
                 
COMMON EQUITY
               
Common stock, $4 par value, authorized 10,000,000
               
  shares; issued and outstanding 8,435,900 shares in 2013
               
  and 2012
    33,744       33,744  
Paid-in capital
    36,294       36,294  
Retained earnings
    134,793       125,527  
TOTAL
    204,831       195,565  
                 
TOTAL LIABILITIES AND EQUITY
  $ 915,859     $ 881,789  
                 
See Notes to Financial Statements.
               


 
STATEMENTS OF CHANGES IN COMMON EQUITY
For the Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
   
Common Equity
       
   
Common
Stock
   
Paid-in Capital
   
Retained
Earnings
   
Total
 
   
(In Thousands)
 
                         
Balance at December 31, 2011
  $ 33,744     $ 36,294     $ 111,127     $ 181,165  
                                 
Net income
    -       -       17,781       17,781  
Common stock dividends
    -       -       (1,700 )     (1,700 )
Preferred stock dividends
    -       -       (724 )     (724 )
                                 
Balance at September 30, 2012
  $ 33,744     $ 36,294     $ 126,484     $ 196,522  
                                 
                                 
Balance at December 31, 2012
  $ 33,744     $ 36,294     $ 125,527     $ 195,565  
                                 
Net income
    -       -       9,990       9,990  
Preferred stock dividends
    -       -       (724 )     (724 )
                                 
Balance at September 30, 2013
  $ 33,744     $ 36,294     $ 134,793     $ 204,831  
                                 
See Notes to Financial Statements.
                               


  
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
                         
   
Three Months Ended
   
Increase/
       
Description
 
2013
   
2012
   
(Decrease)
 
%
 
   
(Dollars In Millions)
       
Electric Operating Revenues:
                   
  Residential
  $ 67     $ 58     $ 9       16  
  Commercial
    55       47       8       17  
  Industrial
    11       9       2       22  
  Governmental
    19       18       1       6  
    Total retail
    152       132       20       15  
  Sales for resale:
                               
     Associated companies
    6       10       (4 )     (40 )
  Other
    4       4       -       -  
    Total
  $ 162     $ 146     $ 16       11  
                                 
Billed Electric Energy
                               
 Sales (GWh):
                               
  Residential
    613       579       34       6  
  Commercial
    576       553       23       4  
  Industrial
    139       130       9       7  
  Governmental
    206       219       (13 )     (6 )
    Total retail
    1,534       1,481       53       4  
  Sales for resale:
                               
     Associated companies
    93       246       (153 )     (62 )
     Non-associated companies
    2       1       1       100  
    Total
    1,629       1,728       (99 )     (6 )
                                 
                                 
   
Nine Months Ended
   
Increase/
         
Description
    2013       2012    
(Decrease)
 
%
 
   
(Dollars In Millions)
         
Electric Operating Revenues:
                         
  Residential
  $ 155     $ 135     $ 20       15  
  Commercial
    140       123       17       14  
  Industrial
    27       23       4       17  
  Governmental
    51       47       4       9  
    Total retail
    373       328       45       14  
  Sales for resale:
                               
     Associated companies
    14       21       (7 )     (33 )
  Other
    10       12       (2 )     (17 )
    Total
  $ 397     $ 361     $ 36       10  
                                 
Billed Electric Energy
                               
 Sales (GWh):
                               
  Residential
    1,438       1,398       40       3  
  Commercial
    1,502       1,507       (5 )     -  
  Industrial
    358       365       (7 )     (2 )
  Governmental
    570       598       (28 )     (5 )
    Total retail
    3,868       3,868       -       -  
  Sales for resale:
                               
     Associated companies
    249       436       (187 )     (43 )
     Non-associated companies
    4       4       -       -  
    Total
    4,121       4,308       (187 )     (4 )
                                 
 
 

ENTERGY TEXAS, INC. AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS


Plan to Spin Off the Utility’s Transmission Business

See the “Plan to Spin Off the Utility’s Transmission Business” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K and herein for a discussion of Entergy’s plan to spin off its transmission business and merge it with a newly formed subsidiary of ITC Holdings Corp., including the planned retirement of debt.

Results of Operations

Net Income

Third Quarter 2013 Compared to Third Quarter 2012

Net income increased $16.6 million primarily due to higher net revenue and higher other income, partially offset by higher other operation and maintenance expenses.

Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Net income increased $10.5 million primarily due to higher net revenue and higher other income, partially offset by higher other operation and maintenance expenses and higher depreciation and amortization expenses.

Net Revenue

Third Quarter 2013 Compared to Third Quarter 2012

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges.  Following is an analysis of the change in net revenue comparing the third quarter 2013 to the third quarter 2012:

   
Amount
   
(In Millions)
     
2012 net revenue
 
$161.7 
Fuel recovery
 
6.5 
Hurricane Rita regulatory asset adjustment
 
6.4 
Volume/weather
 
4.0 
Other
 
2.2 
2013 net revenue
 
$180.8 

The fuel recovery variance is primarily the result of a $6 million adjustment to deferred fuel costs recorded in third quarter 2012 in accordance with a rate order from the PUCT issued in September 2012. See Note 2 to the financial statements in the Form 10-K for further discussion of the PUCT rate order.

The Hurricane Rita regulatory asset adjustment of $6.4 million was recorded in third quarter 2012 in accordance with the rate order from the PUCT issued in September 2012.  See Note 2 to the financial statements in the Form 10-K for further discussion of the PUCT rate order.

 
168

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Management’s Financial Discussion and Analysis



The volume/weather variance is primarily due to an increase of 199 GWh, or 4%, in billed electricity usage, including the effect of favorable weather compared to last year on residential and commercial sales and increased usage in the industrial sector compared to last year as a result of an unplanned outage in the refining industry in the third quarter 2012.

Gross operating revenues and fuel and purchased power expenses

Gross operating revenues increased primarily due to an increase of $20.1 million in fuel cost recovery revenues due to higher fuel rates and favorable weather/volume, as discussed above.

Fuel and purchased power expenses increased primarily due to increases in the average market prices of natural gas and purchased power offset by a decrease in deferred fuel costs due to an adjustment in the third quarter 2012 in accordance with a rate order from the PUCT issued in September 2012.  See Note 2 to the financial statements in the Form 10-K for further discussion of the PUCT rate order.
 
 
Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges.  Following is an analysis of the change in net revenue comparing the nine months ended September 30, 2013 to the nine months ended September 30, 2012:

   
Amount
   
(In Millions)
     
2012 net revenue
 
$421.6 
Retail electric price
 
14.5 
Fuel recovery
 
6.5 
Hurricane Rita regulatory asset adjustment
 
6.4 
Reserve equalization
 
4.1 
Volume/weather
 
3.0 
Purchased power capacity
 
(10.0)
Other
 
(0.2)
2013 net revenue
 
$445.9 

The retail electric price variance is primarily due to an annual base rate increase of $28 million, effective July 2012, as a result of the PUCT’s order in the November 2011 rate case. See Note 2 to the financial statements in the Form 10-K for further discussion of the rate order.

The fuel recovery variance is primarily the result of a $6 million adjustment to deferred fuel costs recorded in third quarter 2012 in accordance with a rate order from the PUCT issued in September 2012. See Note 2 to the financial statements in the Form 10-K for further discussion of the PUCT rate order.

The Hurricane Rita regulatory asset adjustment of $6.4 million was recorded in third quarter 2012 in accordance with the rate order from the PUCT issued in September 2012.  See Note 2 to the financial statements in the Form 10-K for further discussion of the PUCT rate order.

The reserve equalization variance is primarily due to decreased reserve equalization expense as a result of changes in the Entergy System generation mix as compared to the same period in 2012.

The volume/weather variance is primarily due to an increase of 157 GWh, or 1%, in billed electricity usage, including the effect of favorable weather compared to last year on residential sales and increased usage in the industrial sector compared to last year as a result of an unplanned outage in the refining industry in the third quarter 2012.
 
 
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Entergy Texas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis


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

Gross operating revenues and fuel and purchased power expenses

Gross operating revenues increased primarily due to an increase of $81.6 million in gross wholesale revenues as a result of an increase in sales to affiliated customers and higher prices and the annual base rate increase effective July 2012, as discussed above.

Fuel and purchased power expenses increased primarily due to increases in the average market prices of natural gas and purchased power and increased demand, partially offset by a decrease in deferred fuel expense as a result of higher interim fuel refunds in 2013 compared to 2012.

Other Income Statement Variances

Third Quarter 2013 Compared to Third Quarter 2012

Other operation and maintenance expenses increased primarily due to an increase of $4.3 million in compensation and benefit costs primarily due to a decrease in discount rates used to determine net periodic pension and other postretirement benefit costs and a settlement charge related to the payment of lump sum benefits out of the non-qualified pension plan.  See "MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates" in the Form 10-K and Note 6 to the financial statements herein for further discussion of benefits costs. This increase was offset by a decrease related to the amortization of Hurricane Rita storm costs in the third quarter 2012 in accordance with a rate order from the PUCT issued in September 2012. See Note 2 to the financial statements in the Form 10-K for further discussion of the PUCT rate order.

Other income increased primarily due to the reversal in the third quarter 2012 of $6.7 million of disallowed carrying charges on Hurricane Rita storm restoration costs in accordance with a rate order from the PUCT issued in September 2012.  See Note 2 to the financial statements in the Form 10-K for further discussion of the PUCT rate order.

Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Other operation and maintenance expenses increased primarily due to:

·  
an increase of $5.2 million in compensation and benefit costs primarily due to a decrease in discount rates used to determine net periodic pension and other postretirement benefit costs and a settlement charge related to the payment of lump sum benefits out of the non-qualified pension plan.  See "MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates" in the Form 10-K and Note 6 to the financial statements herein for further discussion of benefits costs;
·  
an increase of $2.3 million primarily due to storm damage accruals in accordance with a rate order from PUCT issued in September 2012. See Note 2 to the financial statements in the Form 10-K for further discussion of the PUCT rate order;
·  
an increase of $2.1 million  in distribution contract work relating primarily to vegetation maintenance;
·  
an increase of $2.1 million in fossil-fueled generation expenses primarily due to a higher scope of work done during plant outages in 2013 as compared to the same period in prior year; and
·  
an increase of $1.4 million in insurance expenses primarily due to increases in premiums.

Depreciation and amortization expenses increased primarily due to additions to plant in service and an increase in depreciation rates as a result of the rate order approved by the PUCT in September 2012.  See Note 2 to the financial statements in the Form 10-K for further discussion of the PUCT rate order.



 
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Management’s Financial Discussion and Analysis


Other income increased primarily due to the reversal in the third quarter 2012 of $6.7 million of disallowed carrying charges on Hurricane Rita storm restoration costs in accordance with a rate order from the PUCT issued in September 2012. See Note 2 to the financial statements in the Form 10-K for further discussion of the PUCT rate order.

Income Taxes

The effective income tax rate was 37.7% for the third quarter 2013 and 40.2% for the nine months ended September 30, 2013.  The difference in the effective income tax rate for the third quarter 2013 versus the federal statutory rate of 35% was primarily due to certain book and tax differences related to utility plant items and state income taxes.  The difference in the effective income tax rate for the nine months ended September 30, 2013 versus the federal statutory rate of 35% was primarily due to certain book and tax differences related to utility plant items and state income taxes, partially offset by book and tax differences related to the allowance for equity funds used during construction.

The effective income tax rate was 40.3% for the third quarter 2012 and 41.7% for the nine months ended September 30, 2012.  The differences in the effective tax rates for the third quarter 2012 and the nine months ended September 30, 2012 versus the federal statutory rate of 35% were primarily due to certain book and tax differences related to utility plant items and state income taxes, partially offset by the amortization of investment tax credits and book and tax differences related to the allowance for equity funds used during construction.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2013 and 2012 were as follows:

   
2013
 
2012
   
(In Thousands)
         
Cash and cash equivalents at beginning of period
 
$60,236 
 
$65,289 
         
Cash flow provided by (used in):
       
 
Operating activities
 
167,278 
 
171,985 
 
Investing activities
 
(130,025)
 
(65,518)
 
Financing activities
 
(75,746)
 
(107,340)
Net decrease in cash and cash equivalents
 
(38,493)
 
(873)
         
Cash and cash equivalents at end of period
 
$21,743 
 
$64,416 

Operating Activities

Net cash flow provided by operating activities decreased $4.7 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to:

·  
$86.1 million of fuel cost refunds for the nine months ended September 30, 2013 compared to $67.2 million of fuel cost refunds for the nine months ended September 30, 2012.  See Note 2 to the financial statements herein and in the Form 10-K for discussion of the fuel cost refunds; and
·  
the receipt, in January 2012, of $43 million in System Agreement bandwidth remedy payments required to implement the FERC’s remedy in an October 2011 order for the period June-December 2005.  As of March 31, 2013, all of the $43 million, plus interest, had been credited to Entergy Texas customers, with the final $9.5 million being credited in the first quarter 2013.  See Note 2 to the financial statements herein and in the Form 10-K for a discussion of the System Agreement proceedings.


 
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Entergy Texas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis


This was substantially offset by income tax refunds of $94.2 million for the nine months ended September 30, 2013 compared to income tax payments of $6 million for the nine months ended September 30, 2012.  Entergy Texas had income tax refunds in 2013 in accordance with the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement. The refunds resulted from the utilization of Entergy Texas’s taxable losses against taxable income of other members of the Entergy consolidated group.

Investing Activities

Net cash flow used in investing activities increased $64.5 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to money pool activity and an increase in transmission construction expenditures due to reliability work performed in 2013, offset by lower fossil-fueled generation construction expenditures due to a greater scope of projects in 2012.

Increases in Entergy Texas’s receivable from the money pool are a use of cash flow, and Entergy Texas’s receivable from the money pool increased by $5.9 million for the nine months ended September 30, 2013 compared to decreasing by $50.2 million for the nine months ended September 30, 2012.  The money pool is an inter-company borrowing arrangement designed to reduce Entergy’s subsidiaries’ need for external short-term borrowings.

Financing Activities

Net cash flow used in financing activities decreased $31.6 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to a decrease of $32.4 million in common equity dividends paid.

Capital Structure

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

   
September 30,
 2013
 
December 31,
2012
         
Debt to capital
 
64.1% 
 
65.4% 
Effect of excluding the securitization bonds
 
(12.7%)
 
(13.3%)
Debt to capital, excluding securitization bonds (a)
 
51.4% 
 
52.1% 
Effect of subtracting cash
 
(0.6%) 
 
(1.7%)
Net debt to net capital, excluding securitization bonds (a)
 
50.8% 
 
50.4% 

(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 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 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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Management’s Financial Discussion and Analysis


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 the information provided in the Form 10-K.  Entergy Texas is developing its capital investment plan for 2014 through 2016 and currently anticipates making $748 million in capital investments during that period.  In addition to routine capital spending to maintain operations, the capital investment plan includes specific investments and initiatives such as transmission spending to support economic development projects, reliability, and new compliance projects.

Entergy Texas has obtained short-term borrowing authorization through October 2015 from the FERC under which it may borrow at any one time outstanding, $200 million in the aggregate.  See Note 4 to the financial statements for further discussion of Entergy Texas’s short-term borrowing limits.  Entergy Texas has also obtained an order from the FERC authorizing long-term securities issuances through October 2015.

Entergy Texas’s receivables from the money pool were as follows:

September 30,
2013
 
December 31,
2012
 
September 30,
2012
 
December 31,
2011
(In Thousands)
             
$25,105
 
$19,175
 
$12,981
 
$63,191

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 March 2018.  No borrowings were outstanding under the facility as of September 30, 2013.  See Note 4 to the financial statements herein for additional discussion of the credit facility.

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.  Following is an update to that discussion.

Filings with the PUCT

2013 Rate Case

In September 2013, Entergy Texas filed a rate case requesting a $38.6 million base rate increase reflecting a 10.4% return on common equity based on an adjusted test year ending March 31, 2013.  The rate case also proposed (1) a rough production cost equalization adjustment rider recovering Entergy Texas’s payment to Entergy New Orleans to achieve rough production cost equalization based on calendar year 2012 production costs, (2) a rate case expense rider recovering the cost of the 2013 rate case and certain costs associated with previous rate cases, and (3) a transmission cost recovery factor rider recovering any differences in transmission costs and rate mitigation compared to those included in base rates to the extent the proposed spin-merge transaction with ITC Holdings Corp. is completed.  The rate case filing also includes a request to reconcile $0.9 billion of fuel and purchased power costs and fuel revenues covering the period July 2011 through March 2013.  The fuel reconciliation also reflects special circumstances fuel cost recovery of approximately $22 million of purchased power capacity costs.  A procedural schedule has been set that includes staff testimony due in December 2013 and hearings in January 2014.  If approved, new rates could go into effect as early as April 2014.


 
173

Entergy Texas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis


Fuel and Purchased Power Cost Recovery

In November 2012, Entergy Texas filed a pleading seeking a PUCT finding that special circumstances exist for limited cost recovery of capacity costs associated with two purchased power agreements until such time that these costs are included in base rates or a purchased capacity recovery rider or other recovery mechanism.  In March 2013 the PUCT Staff and intervenors filed a joint motion to dismiss Entergy Texas’s application seeking special circumstances recovery of these capacity costs.  Entergy Texas filed to withdraw this case without prejudice and the judge granted the request in June 2013.

At the April 11, 2013 open meeting, the PUCT Commissioners discussed their view that a purchased power capacity rider was good public policy.   The PUCT issued an order on May 28, 2013 adopting the rule allowing for a purchased power capacity rider, subject to an offsetting adjustment for load growth.  The rule, as adopted, also includes a process for obtaining pre-approval by the PUCT of purchased power agreements.  Entergy Texas has not exercised the option to recover its capacity costs under the new rider mechanism due to the pending base rate case filed with the PUCT in September 2013, but will continue to evaluate the benefits of utilizing the new rider to recover future capacity costs.

Federal Regulation

See “System Agreement” and “Entergy’s Proposal to Join MISO” in the “Rate, Cost-recovery, and Other Regulation – Federal Regulation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis for updates to the Federal Regulation discussion in the Form 10-K.

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.

Nuclear Matters

See “Nuclear Matters” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis 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 unbilled revenue and qualified pension and other postretirement benefits.



CONSOLIDATED INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
                         
   
Three Months Ended
   
Nine Months Ended
 
   
2013
   
2012
   
2013
   
2012
 
   
(In Thousands)
   
(In Thousands)
 
                         
OPERATING REVENUES
                       
Electric
  $ 526,978     $ 489,078     $ 1,288,251     $ 1,174,069  
                                 
OPERATING EXPENSES
                               
Operation and Maintenance:
                               
   Fuel, fuel-related expenses, and
                               
     gas purchased for resale
    101,094       103,542       135,038       178,473  
   Purchased power
    220,490       200,483       647,437       523,208  
   Other operation and maintenance
    60,913       58,343       184,580       170,791  
Taxes other than income taxes
    16,805       19,031       46,506       50,640  
Depreciation and amortization
    23,659       23,043       70,731       64,887  
Other regulatory charges - net
    24,587       23,402       59,897       50,791  
TOTAL
    447,548       427,844       1,144,189       1,038,790  
                                 
OPERATING INCOME
    79,430       61,234       144,062       135,279  
                                 
OTHER INCOME
                               
Allowance for equity funds used during construction
    890       1,281       3,559       3,355  
Interest and investment income
    228       (5,566 )     914       (2,648 )
Miscellaneous - net
    (625 )     (1,520 )     (1,968 )     (3,164 )
TOTAL
    493       (5,805 )     2,505       (2,457 )
                                 
INTEREST EXPENSE
                               
Interest expense
    23,069       24,246       69,401       71,510  
Allowance for borrowed funds used during construction
    (647 )     (1,033 )     (2,533 )     (2,417 )
TOTAL
    22,422       23,213       66,868       69,093  
                                 
INCOME BEFORE INCOME TAXES
    57,501       32,216       79,699       63,729  
                                 
Income taxes
    21,700       12,982       32,023       26,547  
                                 
NET INCOME
  $ 35,801     $ 19,234     $ 47,676     $ 37,182  
                                 
                                 
See Notes to Financial Statements.
                               

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
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CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2013 and 2012
(Unaudited)
             
   
2013
   
2012
 
   
(In Thousands)
 
             
OPERATING ACTIVITIES
           
Net income
  $ 47,676     $ 37,182  
Adjustments to reconcile net income to net cash flow provided by operating activities:
         
  Depreciation and amortization
    70,731       64,887  
  Deferred income taxes, investment tax credits, and non-current taxes accrued
    78,717       28,140  
  Changes in assets and liabilities:
               
    Receivables
    (63,375 )     (15,544 )
    Fuel inventory
    (968 )     (2,650 )
    Accounts payable
    13,450       11,930  
    Taxes accrued
    39,644       (8,545 )
    Interest accrued
    (9,190 )     (9,032 )
    Deferred fuel costs
    (92,604 )     11,543  
    Other working capital accounts
    4,689       (10,244 )
    Provisions for estimated losses
    2,358       3,172  
    Other regulatory assets
    78,433       72,559  
    Pension and other postretirement liabilities
    (8,983 )     (11,158 )
    Other assets and liabilities
    6,700       (255 )
Net cash flow provided by operating activities
    167,278       171,985  
                 
INVESTING ACTIVITIES
               
Construction expenditures
    (133,489 )     (128,199 )
Allowance for equity funds used during construction
    3,559       3,355  
Change in money pool receivable - net
    (5,930 )     50,210  
Remittances to transition charge account
    (68,646 )     (65,325 )
Payments from transition charge account
    74,523       74,441  
Other
    (42 )     -  
Net cash flow used in investing activities
    (130,025 )     (65,518 )
                 
FINANCING ACTIVITIES
               
Retirement of long-term debt
    (50,579 )     (49,192 )
Dividends paid:
               
    Common stock
    (25,000 )     (57,420 )
Other
    (167 )     (728 )
Net cash flow used in financing activities
    (75,746 )     (107,340 )
                 
Net decrease in cash and cash equivalents
    (38,493 )     (873 )
                 
Cash and cash equivalents at beginning of period
    60,236       65,289  
                 
Cash and cash equivalents at end of period
  $ 21,743     $ 64,416  
                 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
               
Cash paid (received) during the period for:
               
  Interest - net of amount capitalized
  $ 75,500     $ 77,264  
  Income taxes
  $ (94,233 )   $ 6,000  
                 
See Notes to Financial Statements.
               

 

CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2013 and December 31, 2012
(Unaudited)
             
   
2013
   
2012
 
   
(In Thousands)
 
             
CURRENT ASSETS
           
Cash and cash equivalents:
           
  Cash
  $ 2,090     $ 528  
   Temporary cash investments
    19,653       59,708  
    Total cash and cash equivalents
    21,743       60,236  
Securitization recovery trust account
    31,378       37,255  
Accounts receivable:
               
  Customer
    85,202       53,836  
  Allowance for doubtful accounts
    (894 )     (680 )
  Associated companies
    91,681       68,750  
  Other
    15,247       10,450  
  Accrued unbilled revenues
    48,677       38,252  
    Total accounts receivable
    239,913       170,608  
Accumulated deferred income taxes
    -       34,988  
Fuel inventory - at average cost
    56,356       55,388  
Materials and supplies - at average cost
    30,020       32,853  
System agreement cost equalization
    6,256       16,880  
Prepaid taxes
    14,024       53,668  
Prepayments and other
    18,542       18,206  
TOTAL
    418,232       480,082  
                 
OTHER PROPERTY AND INVESTMENTS
               
Investments in affiliates - at equity
    693       678  
Non-utility property - at cost (less accumulated depreciation)
    419       638  
Other
    18,025       17,263  
TOTAL
    19,137       18,579  
                 
UTILITY PLANT
               
Electric
    3,554,829       3,475,776  
Construction work in progress
    106,817       90,469  
TOTAL UTILITY PLANT
    3,661,646       3,566,245  
Less - accumulated depreciation and amortization
    1,369,362       1,332,349  
UTILITY PLANT - NET
    2,292,284       2,233,896  
                 
DEFERRED DEBITS AND OTHER ASSETS
               
Regulatory assets:
               
  Regulatory asset for income taxes - net
    129,645       131,287  
  Other regulatory assets (includes securitization property
       of $600,055 as of September 30, 2013 and
       $648,863 as of December 31, 2012)
    1,037,745       1,114,536  
Long-term receivables - associated companies
    28,168       29,510  
Other
    18,181       17,891  
TOTAL
    1,213,739       1,293,224  
                 
TOTAL ASSETS
  $ 3,943,392     $ 4,025,781  
                 
See Notes to Financial Statements.
               
 
 
ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2013 and December 31, 2012
(Unaudited)
                 
      2013       2012  
   
(In Thousands)
 
                 
CURRENT LIABILITIES
               
Accounts payable:
               
  Associated companies
  $ 103,312     $ 88,743  
  Other
    60,216       65,261  
Customer deposits
    38,437       38,859  
Accumulated deferred income taxes
    31,816       -  
Interest accrued
    22,976       32,166  
Deferred fuel costs
    730       93,334  
Pension and other postretirement liabilities
    805       853  
System agreement cost equalization
    -       8,968  
Other
    3,797       2,839  
TOTAL
    262,089       331,023  
                 
NON-CURRENT LIABILITIES
               
Accumulated deferred income taxes and taxes accrued
    1,021,401       1,009,081  
Accumulated deferred investment tax credits
    16,546       17,743  
Other regulatory liabilities
    6,738       6,150  
Asset retirement cost liabilities
    4,286       4,103  
Accumulated provisions
    8,967       6,609  
Pension and other postretirement liabilities
    146,306       155,241  
Long-term debt (includes securitization bonds of
       $639,818 as of September 30, 2013 and
       $690,380 as of December 31, 2012)
    1,567,566       1,617,813  
Other
    32,671       23,872  
TOTAL
   
2,804,481
      2,840,612  
                 
Commitments and Contingencies
               
                 
COMMON EQUITY
               
Common stock, no par value, authorized 200,000,000 shares;
               
  issued and outstanding 46,525,000 shares in 2013 and 2012
    49,452       49,452  
Paid-in capital
    481,994       481,994  
Retained earnings
    345,376       322,700  
TOTAL
    876,822       854,146  
                 
TOTAL LIABILITIES AND EQUITY
  $ 3,943,392     $ 4,025,781  
                 
See Notes to Financial Statements.
               

 

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON EQUITY
For the Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
   
Common Equity
       
   
Common
Stock
   
Paid-in
Capital
   
Retained
Earnings
   
Total
 
   
(In Thousands)
 
                         
Balance at December 31, 2011
  $ 49,452     $ 481,994     $ 367,909     $ 899,355  
                                 
Net income
    -       -       37,182       37,182  
Common stock dividends
    -       -       (57,420 )     (57,420 )
                                 
Balance at September 30, 2012
  $ 49,452     $ 481,994     $ 347,671     $ 879,117  
                                 
                                 
Balance at December 31, 2012
  $ 49,452     $ 481,994     $ 322,700     $ 854,146  
                                 
Net income
    -       -       47,676       47,676  
Common stock dividends
    -       -       (25,000 )     (25,000 )
                                 
Balance at September 30, 2013
  $ 49,452     $ 481,994     $ 345,376     $ 876,822  
                                 
See Notes to Financial Statements.
                               

 
 
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
                         
   
Three Months Ended
   
Increase/
       
Description
 
2013
   
2012
   
(Decrease)
 
%
 
   
(Dollars In Millions)
       
Electric Operating Revenues:
                   
  Residential
  $ 213     $ 192     $ 21       11  
  Commercial
    102       98       4       4  
  Industrial
    98       87       11       13  
  Governmental
    7       6       1       17  
    Total retail
    420       383       37       10  
  Sales for resale:
                               
     Associated companies
    90       92       (2 )     (2 )
     Non-associated companies
    10       8       2       25  
  Other
    7       6       1       17  
    Total
  $ 527     $ 489     $ 38       8  
                                 
Billed Electric Energy
                               
 Sales (GWh):
                               
  Residential
    1,917       1,879       38       2  
  Commercial
    1,291       1,267       24       2  
  Industrial
    1,768       1,634       134       8  
  Governmental
    77       74       3       4  
    Total retail
    5,053       4,854       199       4  
  Sales for resale:
                               
     Associated companies
    1,713       1,982       (269 )     (14 )
     Non-associated companies
    142       179       (37 )     (21 )
    Total
    6,908       7,015       (107 )     (2 )
                                 
                                 
   
Nine Months Ended
   
Increase/
         
Description
    2013       2012    
(Decrease)
 
%
 
   
(Dollars In Millions)
         
Electric Operating Revenues:
                         
  Residential
  $ 450     $ 425     $ 25       6  
  Commercial
    240       248       (8 )     (3 )
  Industrial
    233       226       7       3  
  Governmental
    17       17       -       -  
    Total retail
    940       916       24       3  
  Sales for resale:
                               
     Associated companies
    283       201       82       41  
     Non-associated companies
    28       28       0       -  
  Other
    37       29       8       28  
    Total
  $ 1,288     $ 1,174     $ 114       10  
                                 
Billed Electric Energy
                               
 Sales (GWh):
                               
  Residential
    4,383       4,386       (3 )     -  
  Commercial
    3,306       3,342       (36 )     (1 )
  Industrial
    4,704       4,512       192       4  
  Governmental
    213       209       4       2  
    Total retail
    12,606       12,449       157       1  
  Sales for resale:
                               
     Associated companies
    4,778       4,145       633       15  
     Non-associated companies
    464       683       (219 )     (32 )
    Total
    17,848       17,277       571       3  
                                 



SYSTEM ENERGY RESOURCES, INC.

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS


Results of Operations

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.

Third Quarter 2013 Compared to Third Quarter 2012

Net income increased $4.5 million primarily due to a lower effective income tax rate, partially offset by lower operating income.  The lower effective income tax rate was primarily due to the reversal of a portion of the provision for uncertain tax positions.  Operating income was lower because of lower rate base as compared to 2012.
 
Nine Months Ended September 30, 2013 Compared to Nine Months Ended September 30, 2012

Net income decreased $1.7 million primarily due to lower other income and a higher effective income tax rate, substantially offset by increased operating income.  Other income was lower due to AFUDC accrued on the Grand Gulf uprate project in 2012.  Operating income was higher because of higher rate base compared to 2012 resulting from capital spending at Grand Gulf, including the uprate project. The Grand Gulf’s spring 2012 refueling outage was completed in June 2012, and the majority of uprate-related capital improvements were completed during this outage.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2013 and 2012 were as follows:

   
2013
 
2012
   
(In Thousands)
         
Cash and cash equivalents at beginning of period
 
$83,622 
 
$185,157 
         
Cash flow provided by (used in):
       
 
Operating activities
 
136,814 
 
217,040 
 
Investing activities
 
(59,890)
 
(513,256)
 
Financing activities
 
(156,734)
 
131,297 
Net decrease in cash and cash equivalents
 
(79,810)
 
(164,919)
         
Cash and cash equivalents at end of period
 
$3,812 
 
$20,238 

 
182

System Energy Resources, Inc.
Management’s Financial Discussion and Analysis


Operating Activities

Net cash provided by operating activities decreased $80.2 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to income tax payments of $217.1 million in 2013 compared to income tax refunds of $3.9 million in 2012, partially offset by spending on the Grand Gulf refueling outage in 2012.  System Energy had income tax payments in 2013 in accordance with the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement.  The income tax payments resulted primarily from the reversal of temporary differences for which System Energy had previously claimed a tax deduction.

Investing Activities

Net cash used in investing activities decreased $453.4 million for the nine months ended September 30, 2013 compared to the nine months ended September 30, 2012 primarily due to a decrease in construction expenditures resulting from spending on the uprate project at Grand Gulf completed during the refueling outage in 2012 and a decrease in nuclear fuel activity primarily due to the Grand Gulf refueling outage in 2012.  The decrease was partially offset by money pool activity and $72.2 million of first mortgage bond proceeds deposited with a trustee in September 2012 and used in October 2012 for the redemption of another series of first mortgage bonds.

Decreases in System Energy’s receivable from the money pool are a source of cash flow, and System Energy’s receivable from the money pool decreased $22.9 million for the nine months ended September 30, 2013 compared to decreasing by $116.3 million for the nine months ended September 30, 2012.  The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Financing Activities

System Energy’s financing activities used $156.7 million of cash for the nine months ended September 30, 2013 compared to providing $131.3 million of cash for the nine months ended September 30, 2012 primarily due to the following cash flow activity:

·  
the issuance of $250 million 4.10% Series first mortgage bonds by System Energy Resources in September 2012;
·  
an increase in borrowings of $6.5 million on the nuclear fuel company variable interest entity’s credit facility in 2013 compared to an increase in borrowings of $62.8 million on the nuclear fuel company variable interest entity’s credit facility in 2012;
·  
the redemption of $70 million of 6.29% Series F notes by the nuclear fuel company variable interest entity in September 2013;
·  
the issuance of $50 million of 4.02% Series H notes by the nuclear fuel company variable interest entity in February 2012;
·  
an increase of $17.3 million in common stock dividends paid in 2013; and
·  
the redemption of $152.975 million of pollution control revenue bonds in 2012.


 
183

System Energy Resources, Inc.
Management’s Financial Discussion and Analysis


Capital Structure

System Energy’s capitalization is balanced between equity and debt, as shown in the following table.  The decrease in the debt to capital ratio for System Energy as of September 30, 2013 is primarily due to a decrease in long-term debt as a result of the redemption of $70 million of 6.29% Series F notes, as discussed above, and an increase in retained earnings.

   
September 30,
 2013
 
December 31,
2012
         
Debt to capital
 
45.1% 
 
49.7% 
Effect of subtracting cash
 
(0.1%)
 
(2.6%)
Net debt to net capital
 
45.0%
 
47.1% 

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 is developing its capital investment plan for 2014 through 2016 and currently anticipates making $156 million in capital investments during that period.  In addition to routine capital spending to maintain operations, the capital investment plan includes specific investments and initiatives such as NRC post-Fukushima requirements and plant improvements.

System Energy has obtained a short-term borrowing authorization from the FERC under which it may borrow, through October 2015, up to the aggregate amount, at any one time outstanding, of $200 million.  See Note 4 to the financial statements for further discussion of System Energy’s short-term borrowing limits.  System Energy has also obtained an order from the FERC authorizing long-term securities issuances through October 2015.  System Energy has obtained long-term financing authorization from the FERC that extends through October 2015 for issuances by its nuclear fuel company variable interest entity.

System Energy’s receivables from the money pool were as follows:

September 30,
2013
 
December 31,
2012
 
September 30,
2012
 
December 31,
2011
(In Thousands)
             
$4,008
 
$26,915
 
$4,103
 
$120,424

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

The System Energy nuclear fuel company variable interest entity has a credit facility in the amount of $125 million scheduled to expire in June 2016.  As of September 30, 2013, $46.5 million in letters of credit were outstanding under the credit facility to support a like amount of commercial paper issued by the System Energy nuclear fuel company variable interest entity.  See Note 4 to the financial statements for additional discussion of the variable interest entity credit facility.



 
184

System Energy Resources, Inc.
Management’s Financial Discussion and Analysis


In October 2013 the System Energy Resources nuclear fuel company variable interest entity issued $85 million of 3.78% Series I notes due October 2018.  The System Energy nuclear fuel company variable interest entity used the proceeds to repay outstanding commercial paper and to purchase additional nuclear fuel.

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 System Energy’s accounting for nuclear decommissioning costs and qualified pension and other postretirement benefits.



INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                         
   
Three Months Ended
   
Nine Months Ended
 
   
2013
   
2012
   
2013
   
2012
 
   
(In Thousands)
   
(In Thousands)
 
                         
OPERATING REVENUES
                       
Electric
  $ 192,679     $ 188,680     $ 533,434     $ 428,413  
                                 
OPERATING EXPENSES
                               
Operation and Maintenance:
                               
   Fuel, fuel-related expenses, and
                               
     gas purchased for resale
    26,974       25,538       77,077       38,976  
   Nuclear refueling outage expenses
    7,418       7,304       22,133       14,352  
   Other operation and maintenance
    43,577       38,029       123,955       105,754  
Decommissioning
    8,946       8,327       26,364       24,541  
Taxes other than income taxes
    6,291       5,230       19,264       16,262  
Depreciation and amortization
    51,981       47,991       119,427       102,989  
Other regulatory credits - net
    (4,537 )     (2,673 )     (10,499 )     (7,096 )
TOTAL
    140,650       129,746       377,721       295,778  
                                 
OPERATING INCOME
    52,029       58,934       155,713       132,635  
                                 
OTHER INCOME
                               
Allowance for equity funds used during construction
    2,267       2,171       5,470       24,158  
Interest and investment income
    1,259       2,506       6,450       8,108  
Miscellaneous - net
    (134 )     (146 )     (493 )     (446 )
TOTAL
    3,392       4,531       11,427       31,820  
                                 
INTEREST EXPENSE
                               
Interest expense
    9,756       12,631       28,411       34,076  
Allowance for borrowed funds used during construction
    (223 )     (401 )     (604 )     (6,892 )
TOTAL
    9,533       12,230       27,807       27,184  
                                 
INCOME BEFORE INCOME TAXES
    45,888       51,235       139,333       137,271  
                                 
Income taxes
    10,783       20,619       48,488       44,751  
                                 
NET INCOME
  $ 35,105     $ 30,616     $ 90,845     $ 92,520  
                                 
See Notes to Financial Statements.
                               
                                 
 


 
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2013 and 2012
(Unaudited)
             
   
2013
   
2012
 
   
(In Thousands)
 
OPERATING ACTIVITIES
           
Net income
  $ 90,845     $ 92,520  
Adjustments to reconcile net income to net cash flow provided by operating activities:
         
  Depreciation, amortization, and decommissioning, including nuclear fuel amortization
    206,699       157,070  
  Deferred income taxes, investment tax credits, and non-current taxes accrued
    57,096       106,167  
  Changes in assets and liabilities:
               
    Receivables
    4,180       (8,224 )
    Accounts payable
    (2,039 )     (9,070 )
    Taxes accrued and prepaid taxes
    (219,221 )     (63,879 )
    Interest accrued
    (127 )     (1,636 )
    Other working capital accounts
    17,025       (30,126 )
    Other regulatory assets
    13,724       (38,909 )
    Pension and other postretirement liabilities
    (4,891 )     (9,375 )
    Other assets and liabilities
    (26,477 )     22,502  
Net cash flow provided by operating activities
    136,814       217,040  
                 
INVESTING ACTIVITIES
               
Construction expenditures
    (37,731 )     (415,013 )
Allowance for equity funds used during construction
    5,470       24,158  
Nuclear fuel purchases
    (53,666 )     (182,619 )
Proceeds from the sale of nuclear fuel
    26,522       38,413  
Changes in other investments - net
    -       (72,170 )
Proceeds from nuclear decommissioning trust fund sales
    144,631       315,006  
Investment in nuclear decommissioning trust funds
    (168,023 )     (337,352 )
Changes in money pool receivable - net
    22,907       116,321  
Net cash flow used in investing activities
    (59,890 )     (513,256 )
                 
FINANCING ACTIVITIES
               
Proceeds from the issuance of long-term debt
    -       297,908  
Retirement of long-term debt
    (111,479 )     (192,867 )
Changes in credit borrowings - net
    6,531       62,772  
Dividends paid:
               
  Common stock
    (50,000 )     (32,750 )
Other
    (1,786 )     (3,766 )
Net cash flow provided by (used in) financing activities
    (156,734 )     131,297  
                 
Net decrease in cash and cash equivalents
    (79,810 )     (164,919 )
                 
Cash and cash equivalents at beginning of period
    83,622       185,157  
                 
Cash and cash equivalents at end of period
  $ 3,812     $ 20,238  
                 
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
               
Cash paid (received) during the period for:
               
  Interest - net of amount capitalized
  $ 20,708     $ 27,667  
  Income taxes
  $ 217,089     $ (3,873 )
                 
See Notes to Financial Statements.
               


  
BALANCE SHEETS
ASSETS
September 30, 2013 and December 31, 2012
(Unaudited)
             
   
2013
   
2012
 
   
(In Thousands)
 
             
CURRENT ASSETS
           
Cash and cash equivalents:
           
  Cash
  $ 680     $ 100  
  Temporary cash investments
    3,132       83,522  
    Total cash and cash equivalents
    3,812       83,622  
Accounts receivable:
               
  Associated companies
    67,605       93,381  
  Other
    4,593       5,904  
    Total accounts receivable
    72,198       99,285  
Accumulated deferred income taxes
    21,792       74,331  
Materials and supplies - at average cost
    84,890       82,443  
Deferred nuclear refueling outage costs
    13,664       35,155  
Prepaid taxes
    37,744       -  
Prepayments and other
    4,102       2,080  
TOTAL
    238,202       376,916  
                 
OTHER PROPERTY AND INVESTMENTS
               
Decommissioning trust funds
    563,428       490,572  
TOTAL
    563,428       490,572  
                 
UTILITY PLANT
               
Electric
    4,003,015       3,987,672  
Property under capital lease
    569,355       569,355  
Construction work in progress
    42,870       40,392  
Nuclear fuel
    214,053       252,682  
TOTAL UTILITY PLANT
    4,829,293       4,850,101  
Less - accumulated depreciation and amortization
    2,665,585       2,568,862  
UTILITY PLANT - NET
    2,163,708       2,281,239  
                 
DEFERRED DEBITS AND OTHER ASSETS
               
Regulatory assets:
               
  Regulatory asset for income taxes - net
    120,739       126,503  
  Other regulatory assets
    322,114       330,074  
Other
    16,290       18,212  
TOTAL
    459,143       474,789  
                 
TOTAL ASSETS
  $ 3,424,481     $ 3,623,516  
                 
See Notes to Financial Statements.
               
 
 
SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2013 and December 31, 2012
(Unaudited)
                 
      2013       2012  
   
(In Thousands)
 
                 
CURRENT LIABILITIES
               
Currently maturing long-term debt
  $ 48,653     $ 111,854  
Short-term borrowings
    46,517       39,986  
Accounts payable:
               
  Associated companies
    7,638       5,564  
  Other
    24,936       44,433  
Taxes accrued
    -       181,477  
Accumulated deferred income taxes
    688       1,789  
Interest accrued
    15,492       15,619  
Other
    2,432       2,429  
TOTAL
    146,356       403,151  
                 
NON-CURRENT LIABILITIES
               
Accumulated deferred income taxes and taxes accrued
    783,720       782,469  
Accumulated deferred investment tax credits
    55,427       56,188  
Other regulatory liabilities
    299,145       256,024  
Decommissioning
    504,735       478,371  
Pension and other postretirement liabilities
    137,726       142,617  
Long-term debt
    623,753       671,945  
Other
    45       22  
TOTAL
    2,404,551       2,387,636  
                 
Commitments and Contingencies
               
                 
COMMON EQUITY
               
Common stock, no par value, authorized 1,000,000 shares;
               
  issued and outstanding 789,350 shares in 2013 and 2012
    789,350       789,350  
Retained earnings
    84,224       43,379  
TOTAL
    873,574       832,729  
                 
TOTAL LIABILITIES AND EQUITY
  $ 3,424,481     $ 3,623,516  
                 
See Notes to Financial Statements.
               
 

 
STATEMENTS OF CHANGES IN COMMON EQUITY
For the Nine Months Ended September 30, 2013 and 2012
(Unaudited)
                   
   
Common Equity
       
   
Common
Stock
   
Retained
Earnings
   
Total
 
   
(In Thousands)
 
                   
Balance at December 31, 2011
  $ 789,350     $ 11,213     $ 800,563  
                         
Net income
    -       92,520       92,520  
Common stock dividends
    -       (32,750 )     (32,750 )
                         
Balance at September 30, 2012
  $ 789,350     $ 70,983     $ 860,333  
                         
                         
Balance at December 31, 2012
  $ 789,350     $ 43,379     $ 832,729  
                         
Net income
    -       90,845       90,845  
Common stock dividends
    -       (50,000 )     (50,000 )
                         
Balance at September 30, 2013
  $ 789,350     $ 84,224     $ 873,574  
                         
See Notes to Financial Statements.
                       
                         




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.  Following is an update to that discussion.  Also see "Item 5, Other Information, Environmental Regulation", below, for updates regarding environmental proceedings and regulation.

Texas Power Price Lawsuit

See the Form 10-K for a discussion of the lawsuit filed in August 2003 in the district court of Chambers County, Texas by Texas residents on behalf of a purported class of the Texas retail customers of Entergy Gulf States, Inc. who were billed and paid for electric power from January 1, 1994 to the present.  The case is pending in state district court, and in March 2012 the court found that the case met the requirements to be maintained as a class action under Texas law.  On April 30, 2012, the court entered an order certifying the class.  The defendants have appealed the order to the Texas Court of Appeals – First District.  The appeal is pending, and proceedings in district court are stayed until the appeal is resolved.  Oral arguments before the court of appeals were conducted on April 23, 2013, and the matter awaits that court’s decision.

Item 1A.  Risk Factors

There have been no material changes to the risk factors discussed in "PART I, Item 1A, Risk Factors" in the Form 10-K.

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)
                 
7/01/2013-7/31/2013
 
-
 
$-
 
-
 
$350,052,918
8/01/2013-8/31/2013
 
-
 
$-
 
-
 
$350,052,918
9/01/2013-9/30/2013
 
-
 
$-
 
-
 
$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.  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 2013, Entergy withheld 62,841 shares of its common stock at $64.45 per share to pay income taxes due upon vesting of restricted stock granted 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 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

Nuclear Waste Policy Act of 1982

Spent Nuclear Fuel

See the discussion in Part I, Item 1 in the Form 10-K for information regarding litigation against the DOE related to the DOE’s breach of its obligation to remove spent fuel from nuclear sites.  Following is an update to that discussion.  In April 2013 the U.S. Court of Appeals for the Federal Circuit issued a ruling in favor of Entergy Nuclear FitzPatrick and Entergy Nuclear Indian Point 3 and against the DOE that the DOE may not raise as a defense to damages claims in the spent fuel litigation a claim that it was unavoidably delayed in commencing performance.  In April 2013 the U.S. Treasury paid Entergy Nuclear Generation Company $4.2 million representing the judgment in favor of Entergy Nuclear Generation Company against the DOE for the Pilgrim plant.  In April 2013 the U.S. Treasury paid Entergy Nuclear Vermont Yankee $40.8 million representing the judgment in favor of Entergy Nuclear Vermont Yankee against the DOE for the Vermont Yankee plant.  In April 2013 the U.S. Court of Federal Claims issued a judgment in favor of Entergy Arkansas and against the DOE in the remanded spent fuel case for damages in the amount of $47.8 million and Entergy Arkansas received payment from the U.S. Treasury in August 2013.

Nuclear Plant Decommissioning

See the discussion in Part I, Item 1 in the Form 10-K for information regarding decommissioning funding for the nuclear plants.  Following is an update to that discussion.  In March 2013, Entergy Operations and Entergy Nuclear Operations made filings with the NRC reporting on decommissioning funding for Entergy’s nuclear plants.  Those reports all showed that decommissioning funding for the nuclear plants met the NRC’s financial assurance requirements.

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

Potential SO2 Nonattainment

The EPA issued a final rule in June 2010 adopting an SO2 1-hour national ambient air quality standard of 75 parts per billion.  The EPA designations for counties in attainment and nonattainment were originally due in June 2012, but the EPA has indicated that it will delay designations except for those areas with existing monitoring data from 2009 to 2011 indicating violations of the new standard.  In July 2013 the EPA issued final designations for these areas.  Only St. Bernard Parish in Louisiana is designated as non-attainment for the SO2 1-hour national ambient air quality standard of 75 parts per billion, but Entergy does not have a generation asset in this parish.  In all other areas, analysis is required once the EPA issues additional final regulations and guidance.  Additional capital projects or operational changes may be required for Entergy facilities in these areas.

Hazardous Air Pollutants

The EPA released the final Mercury and Air Toxics Standard (MATS) rule in December 2011 and the rule became effective in April 2012.  Entergy currently is developing compliance plans to meet requirements of the rule, which could result in significant capital expenditures for Entergy’s coal-fired units.  Compliance with MATS is required by the Clean Air Act within three years, or by 2015, although certain extensions of this deadline are available from state permit authorities and the EPA.  Entergy has applied for and received a one-year extension, as allowed by the Clean Air Act, for its affected facilities in Arkansas and Louisiana.



Cross-State Air Pollution

See the Form 10-K for a discussion of the Clean Air Interstate Rule (CAIR) and the Cross-State Air Pollution Rule (CSAPR, which previously was referred to as the Transport Rule).  In December 2011 the Court of Appeals for the D.C. Circuit stayed CSAPR and instructed the EPA to continue administering CAIR, pending further judicial review.  In August 2012 the court issued a decision vacating CSAPR and leaving CAIR in place pending the promulgation of a lawful replacement for both rules.  In January 2013 the court denied petitions for reconsideration filed by the EPA and certain states and intervenors.  In March 2013 the EPA and other parties filed petitions for certiorari with the U.S. Supreme Court.  The U.S. Supreme Court issued an order in June 2013 granting the EPA’s and environmental groups’ petitions for review of the D.C. Circuit’s decision vacating CSAPR.  Entergy is complying with CAIR as it continues to be implemented until further instruction from the courts or the EPA.

New Source Performance Standards for Greenhouse Gas Emissions

As a part of a climate plan announced June 25, 2013, President Obama directed the EPA to (i) reissue proposed carbon pollution standards for new power plants by September 20, 2013, with finalization of the rules to occur in a timely manner; (ii) issue proposed carbon pollution standards, regulations, or guidelines, as appropriate, for modified, reconstructed, and existing power plants no later than June 1, 2014; (iii) finalize those rules by no later than June 1, 2015; and (iv) include in the guidelines addressing existing power plants a requirement that states submit to the EPA the implementation plans required under Section 111(d) of the Clean Air Act and its implementing regulations by no later than June 30, 2016.  In September 2013 the EPA issued the proposed new source performance standards (NSPS) rule for new sources and is currently conducting stakeholder meetings in preparation for issuing the proposed NSPS rule for existing sources in 2014.  Entergy is involved in both processes.

Clean Water Act

Effluent Limitation Guidelines

In April 2013 the EPA issued proposed effluent limitation guidelines that, if adopted as final, would apply to discharges from Entergy’s generating facilities that hold national pollutant discharge elimination system permits under the Clean Water Act.  The proposal includes several options for public consideration.  Entergy submitted comments on the proposed rule and will continue to engage in the public comment process as appropriate. 

Indian Point Units 1 and 2 Hazardous Waste Remediation

Prior to Entergy’s purchase of Indian Point Unit 1, the previous owner completed the cleanup and desludging of the Unit 1 water storage pool, generating mixed waste.  The existing mixed waste storage permit and an associated order on consent were transferred to Entergy upon purchasing the unit.  The waste is stored in the Unit 1 containment building in accordance with NRC regulations controlling low level radioactive waste.  An order on consent with NYSDEC requires a quarterly survey of the availability of any commercial facility capable of treating, processing, and disposing of this waste in a commercially reasonable manner.  However, in 2005, NYSDEC revised its regulations to conditionally exempt the storage and disposal of mixed waste that is regulated by the NRC.   Thus, in October 2005 and again in January 2013, Entergy requested that NYSDEC terminate the mixed waste permit and order on consent because the waste falls within the mixed waste exemption.  On April 26, 2013, NYSDEC agreed with Entergy’s request to terminate the permit finding that as long as the facility continues to meet the exemption, the mixed waste permit is not required.  NYSDEC denied the request to terminate the consent order, however, reasoning that it contains provisions for storage and reporting that are still applicable.    Therefore, pursuant to the terms of the order on consent, Entergy continues to review this matter and to conduct its quarterly searches for a commercially reasonable vendor that is acceptable both to the NRC and the NYSDEC.



Earnings Ratios (Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

The Registrant Subsidiaries have calculated ratios of earnings to fixed charges and ratios of earnings to combined fixed charges and preferred dividends/distributions pursuant to Item 503 of Regulation S-K of the SEC as follows:

 
Ratios of Earnings to Fixed Charges
 
Twelve Months Ended
 
December 31,
 
September 30,
 
2008
 
2009
 
2010
 
2011
 
2012
 
2013
                       
Entergy Arkansas
2.33
 
2.39
 
3.91
 
4.31
 
3.79
 
3.62
Entergy Gulf States Louisiana
2.44
 
2.99
 
3.58
 
4.36
 
3.48
 
3.45
Entergy Louisiana
3.14
 
3.52
 
3.41
 
1.86
 
2.08
 
3.08
Entergy Mississippi
2.92
 
3.31
 
3.35
 
3.55
 
2.79
 
3.10
Entergy New Orleans
3.71
 
3.61
 
4.43
 
5.37
 
3.02
 
2.00
Entergy Texas
2.04
 
1.92
 
2.10
 
2.34
 
1.76
 
1.95
System Energy
3.29
 
3.73
 
3.64
 
3.85
 
5.12
 
5.73

 
Ratios of Earnings to Combined Fixed Charges
and Preferred Dividends/Distributions
 
Twelve Months Ended
 
December 31,
 
September 30,
 
 
2008
 
2009
 
2010
 
2011
 
2012
 
2013
 
                         
Entergy Arkansas
1.95
 
2.09
 
3.60
 
3.83
 
3.36
 
3.23
 
Entergy Gulf States Louisiana
2.42
 
2.95
 
3.54
 
4.30
 
3.43
 
3.40
 
Entergy Louisiana
2.87
 
3.27
 
3.19
 
1.70
 
1.93
 
2.86
 
Entergy Mississippi
2.67
 
3.06
 
3.16
 
3.27
 
2.59
 
2.88
 
Entergy New Orleans
3.45
 
3.33
 
4.08
 
4.74
 
2.67
 
1.80
 

The Registrant Subsidiaries accrue interest expense related to unrecognized tax benefits in income tax expense and do not include it in fixed charges.

Item 6.  Exhibits *

*
4(a)
Seventy-eighth Supplemental Indenture, dated as of August 1, 2013, to Entergy Louisiana, LLC Mortgage and Deed of Trust, dated as of April 1, 1944 (4.08 to Form 8-K dated August 23, 2013 in 1-32718).
     
 
12(a) -
Entergy Arkansas’s Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Dividends, as defined.
     
 
12(b) -
Entergy Gulf States Louisiana’s Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Distributions, as defined.
     
 
12(c) -
Entergy Louisiana’s Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Distributions, as defined.
     
 
12(d) -
Entergy Mississippi’s Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Dividends, as defined.
     
 
12(e) -
Entergy New Orleans’s Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Pre­ferred Dividends, as defined.
     
 
 
 
 
12(f) -
Entergy Texas’s Computation of Ratios of Earnings to Fixed Charges, as defined.
     
 
12(g) -
System Energy’s Computation of Ratios of Earnings to Fixed Charges, as defined.
     
 
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 Gulf States Louisiana.
     
 
31(f) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy Gulf States Louisiana.
     
 
31(g) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy Louisiana.
     
 
31(h) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy Louisiana.
     
 
31(i) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy Mississippi.
     
 
31(j) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy Mississippi.
     
 
31(k) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy New Orleans.
     
 
31(l) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy New Orleans.
     
 
31(m) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy Texas.
     
 
31(n) -
Rule 13a-14(a)/15d-14(a) Certification for Entergy Texas.
     
 
31(o) -
Rule 13a-14(a)/15d-14(a) Certification for System Energy.
     
 
31(p) -
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 Gulf States Louisiana.
     
 
32(f) -
Section 1350 Certification for Entergy Gulf States Louisiana.
     
 
32(g) -
Section 1350 Certification for Entergy Louisiana.
     
 
32(h) -
Section 1350 Certification for Entergy Louisiana.
     
 
32(i) -
Section 1350 Certification for Entergy Mississippi.
     
 
32(j) -
Section 1350 Certification for Entergy Mississippi.
     
 
 
 
 
 
 
32(k) -
Section 1350 Certification for Entergy New Orleans.
     
 
32(l) -
Section 1350 Certification for Entergy New Orleans.
     
 
32(m) -
Section 1350 Certification for Entergy Texas.
     
 
32(n) -
Section 1350 Certification for Entergy Texas.
     
 
32(o) -
Section 1350 Certification for System Energy.
     
 
32(p) -
Section 1350 Certification for System Energy.
     
 
101 INS -
XBRL Instance Document.
     
 
101 SCH -
XBRL Taxonomy Extension Schema Document.
     
 
101 PRE -
XBRL Taxonomy Presentation Linkbase Document.
     
 
101 LAB -
XBRL Taxonomy Label Linkbase Document.
     
 
101 CAL -
XBRL Taxonomy Calculation Linkbase Document.
     
 
101 DEF -
XBRL Definition Linkbase Document.
___________________________

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.

*
Incorporated herein by reference as indicated.


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, INC.
ENTERGY GULF STATES LOUISIANA, L.L.C.
ENTERGY LOUISIANA, LLC
ENTERGY MISSISSIPPI, INC.
ENTERGY NEW ORLEANS, INC.
ENTERGY TEXAS, INC.
SYSTEM ENERGY RESOURCES, INC.
 
 
/s/ Alyson M. Mount
Alyson M. Mount
Senior Vice President and Chief Accounting Officer
(For each Registrant and for each as
Principal Accounting Officer)


Date:           November 7, 2013


 
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