__________________________________________________________________________________________

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, 2006

 

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, Address of
Principal Executive Offices, Telephone Number, and
IRS Employer Identification No.

 


Commission
File Number

Registrant, State of Incorporation, Address of
Principal Executive Offices, Telephone Number, and
IRS Employer Identification No.

1-11299

ENTERGY CORPORATION
(a Delaware corporation)
639 Loyola Avenue
New Orleans, LA 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

 

0-5807

ENTERGY NEW ORLEANS, INC.
(a Louisiana corporation)
1600 Perdido Street, Building 529
New Orleans, Louisiana 70112
Telephone (504) 670-3620
72-0273040

         

1-27031

ENTERGY GULF STATES, INC.
(a Texas corporation)
350 Pine Street
Beaumont, Texas 77701
Telephone (409) 838-6631
74-0662730

 

1-9067

SYSTEM ENERGY RESOURCES, INC.
(an Arkansas corporation)
Echelon One
1340 Echelon Parkway
Jackson, Mississippi 39213
Telephone (601) 368-5000
72-0752777

         

1-32718

ENTERGY LOUISIANA, LLC
(a Texas limited liability company)
446 North Boulevard
Baton Rouge, LA 70802
Telephone (225) 381-5868
75-3206126

     

__________________________________________________________________________________________

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

X

No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of "accelerated filer and large accelerated filer" in Rule 12b-2 of the Exchange Act.

 

Large
accelerated
filer

 



Accelerated filer

 


Non-accelerated filer

Entergy Corporation

Ö

       

Entergy Arkansas, Inc.

       

Ö

Entergy Gulf States, Inc.

       

Ö

Entergy Louisiana, LLC

       

Ö

Entergy Mississippi, Inc.

       

Ö

Entergy New Orleans, 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

No

X

Common Stock Outstanding

 

Outstanding at October 31, 2006

Entergy Corporation

($0.01 par value)

206,861,148 shares

Entergy Corporation, Entergy Arkansas, Inc., Entergy Gulf States, Inc., Entergy Louisiana, LLC, Entergy Mississippi, Inc., Entergy New Orleans, 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, 2005, and the Quarterly Reports on Form 10-Q for the quarters ended March 31, 2006 and June 30, 2006 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, 2006

 

Page Number

   

Definitions

1

Entergy Corporation and Subsidiaries

 
 

Management's Financial Discussion and Analysis

 
   

Hurricane Katrina and Hurricane Rita

4

   

Results of Operations

8

   

Liquidity and Capital Resources

14

   

Significant Factors and Known Trends

18

   

Critical Accounting Estimates

26

   

Recently Issued Accounting Pronouncements

27

 

Consolidated Statements of Income

29

 

Consolidated Statements of Cash Flows

30

 

Consolidated Balance Sheets

32

 

Consolidated Statements of Retained Earnings, Comprehensive Income, and Paid-In Capital

34

 

Selected Operating Results

35

 

Notes to Consolidated Financial Statements

36

Entergy Arkansas, Inc.

 
 

Management's Financial Discussion and Analysis

 
   

Results of Operations

51

   

Liquidity and Capital Resources

55

   

Significant Factors and Known Trends

57

   

Critical Accounting Estimates

58

   

Recently Issued Accounting Pronouncements

58

 

Income Statements

60

 

Statements of Cash Flows

61

 

Balance Sheets

62

 

Selected Operating Results

64

Entergy Gulf States, Inc.

 
 

Management's Financial Discussion and Analysis

 
   

Hurricane Rita and Hurricane Katrina

65

   

Results of Operations

66

   

Liquidity and Capital Resources

71

   

Significant Factors and Known Trends

73

   

Critical Accounting Estimates

75

   

Recently Issued Accounting Pronouncements

75

 

Income Statements

76

 

Statements of Cash Flows

77

 

Balance Sheets

78

 

Statements of Retained Earnings and Comprehensive Income

80

 

Selected Operating Results

81

Entergy Louisiana, LLC

 
 

Management's Financial Discussion and Analysis

 
   

Hurricane Rita and Hurricane Katrina

82

   

Results of Operations

83

   

Liquidity and Capital Resources

87

   

Significant Factors and Known Trends

89

   

Critical Accounting Estimates

89

   

Recently Issued Accounting Pronouncements

90

 

Income Statements

91

 

Statements of Cash Flows

93

 

Balance Sheets

94

 

Statements of Members' Equity

96

 

Selected Operating Results

97

ENTERGY CORPORATION AND SUBSIDIARIES
INDEX TO QUARTERLY REPORT ON FORM 10-Q
September 30, 2006

 

Page Number

Entergy Mississippi, Inc.

 
 

Management's Financial Discussion and Analysis

 
   

Hurricane Katrina

98

   

Results of Operations

99

   

Liquidity and Capital Resources

102

   

Significant Factors and Known Trends

104

Critical Accounting Estimates

105

   

Recently Issued Accounting Pronouncements

105

 

Income Statements

106

 

Statements of Cash Flows

107

 

Balance Sheets

108

 

Selected Operating Results

110

Entergy New Orleans, Inc.

 
 

Management's Financial Discussion and Analysis

 
   

Hurricane Katrina

111

   

Bankruptcy Proceedings

112

   

Results of Operations

113

   

Liquidity and Capital Resources

116

   

Significant Factors and Known Trends

118

   

Critical Accounting Estimates

119

   

Recently Issued Accounting Pronouncements

120

 

Income Statements

121

 

Statements of Cash Flows

123

 

Balance Sheets

124

 

Selected Operating Results

126

System Energy Resources, Inc.

 
 

Management's Financial Discussion and Analysis

 
   

Results of Operations

127

   

Liquidity and Capital Resources

127

   

Significant Factors and Known Trends

129

   

Critical Accounting Estimates

129

   

Recently Issued Accounting Pronouncements

129

 

Income Statements

130

 

Statements of Cash Flows

131

 

Balance Sheets

132

Notes to Respective Financial Statements

134

Part I, Item 4. Controls and Procedures

150

Part II. Other Information

 
 

Item 1. Legal Proceedings

151

 

Item 1A. Risk Factors

152

 

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

152

 

Item 5. Other Information

153

 

Item 6. Exhibits

154

Signature

157

FORWARD-LOOKING INFORMATION

In this filing and from time to time, Entergy makes statements 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. Although Entergy believes that these forward-looking statements and the underlying assumptions are reasonable, it cannot provide assurance that they will prove correct. Except to the extent required by the federal securities laws, Entergy undertakes 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, and there are factors that could cause actual results to differ materially from those expressed or implied in the statements. Some of those factors (in addition to the risk factors in the Form 10-K as well as others described elsewhere in this report and in subsequent securities filings) include:

 

(Page left blank intentionally)

 

 

 

DEFINITIONS

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

Abbreviation or Acronym

Term

AFUDC

Allowance for Funds Used During Construction

ANO 1 and 2

Units 1 and 2 of Arkansas Nuclear One Steam Electric Generating Station (nuclear), owned by Entergy Arkansas

APSC

Arkansas Public Service Commission

average contract price per MWh or
per kW per month

Price at which generation output and/or capacity is expected to be sold to third parties, given existing contract or option exercise prices based on expected dispatch or capacity

average contract revenue per MWh

Price at which the combination of generation output and capacity are expected to be sold to third parties, given existing contract or option exercise prices based on expected dispatch

Board

Board of Directors of Entergy Corporation

bundled capacity and energy contract

A contract for the sale of installed capacity and related energy, priced per MWh sold

capacity contract

For Non-Utility Nuclear, a contract for the sale of the installed capacity product in regional markets managed by ISO New England and the New York Independent System Operator; For Entergy's non-nuclear wholesale assets business, a contract for the sale of capacity and related energy, in which capacity and energy are priced separately

capacity factor

Actual plant output divided by maximum potential plant output for the period

City Council or Council

Council of the City of New Orleans, Louisiana

DOE

United States Department of Energy

domestic utility companies

Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, collectively

EITF

FASB's Emerging Issues Task Force

Energy Commodity Services

Entergy's business segment that includes Entergy-Koch, LP and Entergy's non-nuclear wholesale assets business

Entergy

Entergy Corporation and its direct and indirect subsidiaries

Entergy Corporation

Entergy Corporation, a Delaware corporation

Entergy-Koch

Entergy-Koch, LP, a joint venture equally owned by subsidiaries of Entergy and Koch Industries, Inc.

EPA

United States Environmental Protection Agency

FASB

Financial Accounting Standards Board

FEMA

Federal Emergency Management Agency

FERC

Federal Energy Regulatory Commission

firm liquidated damages

Transaction that requires receipt or delivery of energy at a specified delivery point (usually at a market hub not associated with a specific asset) or settles financially on notional quantities; if a party fails to deliver or receive energy, the defaulting party must compensate the other party as specified in the contract

1

DEFINITIONS (Continued)

Abbreviation or Acronym

Term

FSP

FASB Staff Position

Grand Gulf

Unit No. 1 of Grand Gulf Steam Electric Generating 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

IRS

Internal Revenue Service

ISO

Independent System Operator

kV

Kilovolt

kW

Kilowatt

kWh

Kilowatt-hour(s)

LDEQ

Louisiana Department of Environmental Quality

LPSC

Louisiana Public Service Commission

Mcf

One thousand cubic feet of gas

MMBtu

One million British Thermal Units

MPSC

Mississippi Public Service Commission

MW

Megawatt(s), which equals one thousand kilowatts

MWh

Megawatt-hour(s)

Nelson Unit 6

Unit No. 6 (coal) of the Nelson Steam Electric Generating Station, owned 70% by Entergy Gulf States

Net debt ratio

Gross debt less cash and cash equivalents divided by total capitalization less cash and cash equivalents

Net MW in operation

Installed capacity owned or operated

Net revenue

Operating revenue net of fuel, fuel-related, and purchased power expenses; and other regulatory credits

Non-Utility Nuclear

Entergy's business segment that primarily owns and operates five nuclear power plants and sells electric power produced by those plants primarily to wholesale customers

NRC

Nuclear Regulatory Commission

NYPA

Power Authority of the State of New York

OASIS

Open Access Same Time Information System

percent of planned generation
sold forward

Percent of planned generation output sold forward under contracts, forward physical contracts, forward financial contracts, or options that may or may not require regulatory approval

planned net MW in operation

Amount of capacity to be available to generate power considering uprates planned to be completed within the calendar year

planned TWh of generation

Amount of output expected to be generated by Non-Utility Nuclear for nuclear units, or by non-nuclear wholesale assets for fossil and wind units, considering plant operating characteristics, outage schedules, and expected market conditions that affect dispatch

PPA

Purchased power agreement

PRP

Potentially responsible party (a person or entity that may be responsible for remediation of environmental contamination)

PUCT

Public Utility Commission of Texas

PUHCA 1935

Public Utility Holding Company Act of 1935, as amended

PUHCA 2005

Public Utility Holding Company Act of 2005, which repealed PUHCA 1935, among other things

2

DEFINITIONS (Concluded)

Abbreviation or Acronym

Term

PURPA

Public Utility Regulatory Policies Act of 1978

Ritchie Unit 2

Unit 2 of the R.E. Ritchie Steam Electric Generating Station (gas/oil)

River Bend

River Bend Steam Electric Generating Station (nuclear), owned by Entergy Gulf States

SEC

United States Securities and Exchange Commission

SFAS

Statement of Financial Accounting Standards as promulgated by the FASB

SMEPA

South Mississippi Electric Power Agency, which owns a 10% interest in Grand Gulf

System Agreement

Agreement, effective January 1, 1983, as modified, among the domestic utility companies relating to the sharing of generating capacity and other power resources

System Energy

System Energy Resources, Inc.

System Fuels

System Fuels, Inc.

TWh

Terawatt-hour(s), which equals one billion kWh, or one million MWh

unit-contingent

Transaction under which power is supplied from a specific generation asset; if the asset is unavailable, the seller is not liable to the buyer for any damages

unit-contingent with
availability guarantees

Transaction under which power is supplied from a specific generation asset; if the asset is unavailable, the seller is not liable to the buyer for any damages unless the actual availability over a specified period of time is below an availability threshold specified in the contract

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

Waterford 3

Unit No. 3 (nuclear) of the Waterford Steam Electric Generating Station, 100% owned or leased by Entergy Louisiana

weather-adjusted usage

Electric usage excluding the estimated effects of deviations from normal weather

White Bluff

White Bluff Steam Electric Generating Station, 57% owned by Entergy Arkansas

3

ENTERGY CORPORATION AND SUBSIDIARIES

MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS

Entergy operates primarily through two business segments: Utility and Non-Utility Nuclear.

In addition to its two primary, reportable, operating segments, Entergy also operates the Energy Commodity Services segment and the Competitive Retail Services business.

Energy Commodity Services includes Entergy-Koch, LP and Entergy's non-nuclear wholesale assets business. Entergy-Koch sold its businesses in the fourth quarter of 2004 and is no longer an operating entity. Due to the November 2006 expiration of contingencies on the sale of Entergy-Koch's trading business, and the corresponding release to Entergy-Koch of sales proceeds held in escrow, Entergy expects to record a gain related to this investment of approximately $60 million, net-of-tax, in the fourth quarter of 2006. In April 2006, Entergy sold the retail electric portion of the Competitive Retail Services business operating in the ERCOT region of Texas, and now reports this portion of the business as a discontinued operation. Entergy reports Energy Commodity Services and Competitive Retail Services as part of All Other in its segment disclosures.

Hurricane Katrina and Hurricane Rita

See the Form 10-K for a discussion of the effects of Hurricanes Katrina and Rita, which in August and September 2005 caused catastrophic damage to portions of the Utility's service territory in Louisiana, Mississippi, and Texas, including the effect of extensive flooding that resulted from levee breaks in and around the greater New Orleans area. Following are updates to the discussion in the Form 10-K.

Community Development Block Grants (CDBG)

As discussed in the Form 10-K, a federal hurricane aid package became law that includes funding for Community Development Block Grants (CDBG) that allows state and local leaders to fund individual recovery priorities. The law permits funding for infrastructure restoration. The U.S. Department of Housing and Urban Development has allocated approximately $10.4 billion for Louisiana, $5.5 billion for Mississippi, and $0.5 billion for Texas. The states, in turn, will administer the grants.

Entergy New Orleans, Entergy Louisiana, and Entergy Gulf States-Louisiana provided justification statements to state and local officials in March 2006 and presented revised justification statements to the Louisiana Recovery Authority in September 2006. The statements include the estimated costs of Hurricanes Katrina and Rita damage, as well as for Entergy New Orleans a lost customer base component intended to help offset the need for storm-related rate increases. The statements include justification for CDBG funding of $592 million for Entergy New Orleans, $539 million for Entergy Louisiana, and $183 million for Entergy Gulf States-Louisiana.

In October 2006, the Louisiana Recovery Authority Board endorsed a resolution proposing to allocate $200 million in CDBG funds to Entergy New Orleans to defray gas and electric utility system repair costs in an effort to provide rate relief for Entergy New Orleans customers. The proposal will now be developed as an action plan amendment and published for public comment. Once public input is reviewed and considered, the final plan will come before the Louisiana Recovery Authority Board, the Governor, and the Louisiana Legislature for approval before submission of the plan to the U.S. Department of Housing and Urban Development for its approval. The City Council will certify Entergy New Orleans' repair costs before they are submitted for funding. The Louisiana Recovery Authority Board has not allocated any CDBG funds to Entergy Louisiana and Entergy Gulf States-Louisiana at this time.

4

As discussed further below, Entergy Mississippi filed a request with the Mississippi Development Authority for CDBG funding for reimbursement of its Hurricane Katrina infrastructure restoration costs and received $81 million in October 2006.

Storm Costs Recovery Filings with Retail Regulators

On July 31, 2006, Entergy Louisiana and Entergy Gulf States filed a supplemental and amending storm cost recovery application with the LPSC, in which Entergy Louisiana and Entergy Gulf States requested that the LPSC (1) review Entergy Louisiana's and Entergy Gulf States' testimony and exhibits relating to the costs associated with Hurricanes Katrina and Rita, and declare that those verified, actual storm-related costs through May 31, 2006 are $466.8 million for Entergy Louisiana and $200.3 million for Entergy Gulf States in the Louisiana jurisdiction and that those costs were prudently incurred; (2) declare that the annual revenue requirements associated with the recovery of those costs, including carrying costs, based on a ten-year levelized rate are $54.4 million for Entergy Louisiana and $26.2 million for Entergy Gulf States; (3) authorize Entergy Louisiana and Entergy Gulf States to recover the costs through Storm Cost Recovery Riders (SCRRs) proposed by Entergy Louisiana and Entergy Gulf States; (4) declare that the storm costs incurred subsequent to May 31, 2006 are to be filed by Entergy Louisiana and Entergy Gulf States with the LPSC on an annual basis in connection with their annual formula rate plan (FRP) filings, and that the SCRRs be adjusted annually to reflect such costs and any insurance proceeds or CDBG funds actually received, with the adjusted amounts to be collected through the SCRRs to take effect contemporaneous with the effective date of rate changes under the FRP; (5) declare that the storm-related costs incurred by Entergy Louisiana and Entergy Gulf States meet the conditions set forth in the FRP for exclusion from the sharing provisions in those FRPs and authorize the permanent recovery of storm costs outside of the FRPs adopted by the LPSC for Entergy Louisiana and Entergy Gulf States; and (6) authorize the funding of a storm reserve through securitization sufficient to fund a storm cost reserve of $132 million for Entergy Louisiana and $81 million for Entergy Gulf States. Hearings are scheduled for March 2007. Entergy Gulf States and Entergy Louisiana also intend to pursue securitization options for the storm cost recovery as well, which is authorized by a law signed by the Governor of Louisiana in May 2006.

In July 2006, Entergy Gulf States filed an application with the PUCT with respect to the $393.2 million of Hurricane Rita reconstruction costs incurred in its Texas retail jurisdiction through March 31, 2006. The filing asks the PUCT to determine that $393.2 million is the amount of reasonable and necessary hurricane reconstruction costs eligible for securitization and recovery, approve the recovery of carrying costs, and approve the manner in which Entergy Gulf States allocates those costs among its Texas retail customer classes.  If approved, Entergy Gulf States' application will ultimately affect all its retail customers in Texas. Entergy Gulf States' filing does not request recovery of costs through a specific rider on customer bills or through any other means at this time. This is the first of two filings authorized by a law passed earlier this year in a special session of the Texas Legislature. A hearing before the PUCT on the filing was scheduled for November 1-3, 2006, but at the commencement of the hearing all of the parties in attendance announced that they had reached a unanimous agreement in principle to settle the issues in the proceeding. The parties are developing the documentation to formalize the settlement. The parties intend to submit the settlement documents to the PUCT prior to Thanksgiving 2006 so that the PUCT can approve them by early December 2006. A second filing will request securitization and recovery of the costs eligible for securitization through retail rates and tariffs. Entergy Gulf States expects to make the second filing following the conclusion of the reconstruction cost case.

In March 2006, the Governor of Mississippi signed a law that established a mechanism by which the MPSC could authorize and certify an electric utility financing order and the state could issue general obligation bonds to finance the costs of repairing damage caused by Hurricane Katrina to the systems of investor-owned electric utilities.  Because of the passage of this law and the possibility of Entergy Mississippi obtaining CDBG funds for Hurricane Katrina storm restoration costs, in March 2006, the MPSC issued an order approving a Joint Stipulation between Entergy Mississippi

 

5

 

and the Mississippi Public Utilities Staff that provided for a review of Entergy Mississippi's total storm restoration costs in an Application for an Accounting Order proceeding.  The Stipulation stated that the procedural schedule of Entergy Mississippi's December 2005 filing seeking recovery of hurricane costs through an existing Entergy Mississippi storm damage rider should be suspended until the MPSC issues a final order in the Application for an Accounting Order proceeding. 

In June 2006, the MPSC issued an order certifying Entergy Mississippi's Hurricane Katrina restoration costs incurred through March 31, 2006 of $89 million, net of estimated insurance proceeds. Two days later, Entergy Mississippi filed a request with the Mississippi Development Authority for $89 million of CDBG funding for reimbursement of its Hurricane Katrina infrastructure restoration costs. Entergy Mississippi also filed a Petition for Financing Order with the MPSC for authorization of state general obligation bond financing of $169 million for Hurricane Katrina restoration costs and future storm costs. The $169 million amount included the $89 million of Hurricane Katrina restoration costs plus $80 million to build Entergy Mississippi's storm damage reserve for the future. Entergy Mississippi's filing stated that the amount actually financed through the state bonds would be net of any CDBG funds that Entergy Mississippi received.

In October 2006, the Mississippi Development Authority approved for payment and Entergy Mississippi received $81 million in CDBG funding for Hurricane Katrina costs. The MPSC then issued a financing order authorizing the issuance of $48 million of state general obligation bonds, with $8 million for the remainder of Entergy Mississippi's certified Hurricane Katrina restoration costs and $40 million for the increase in Entergy Mississippi's storm damage reserve. $30 million of the storm reserve will be set aside in a restricted account. Entergy Mississippi expects to forward the financing order to the state bond commission, as per the March 2006 law, and expects to receive the proceeds from the state general obligation bond issuance in the first quarter of 2007.

See State and Local Rate Regulation below for a discussion of Entergy New Orleans' filings with the City Council directed at recovery of its storm costs.

Insurance Recovery

As discussed more fully in the Form 10-K, the domestic utility companies affected by Hurricanes Katrina and Rita are pursuing insurance recoveries for their covered losses caused by Hurricanes Katrina and Rita. The domestic utility companies have received $37 million thus far on their insurance claims. Entergy currently expects to receive payment for the majority of its estimated insurance recoveries related to Hurricanes Katrina and Rita through 2009.

Entergy New Orleans Bankruptcy

On October 23, 2006 Entergy New Orleans filed a plan of reorganization and a disclosure statement with the bankruptcy court. Objections to the disclosure statement must be filed by November 29, 2006, and a hearing regarding its adequacy is scheduled for December 7, 2006. The period within which Entergy New Orleans has the exclusive right to solicit acceptance of its plan of reorganization will expire on December 22, 2006, unless it is further extended by the bankruptcy court.

The bankruptcy court also extended the time within which Entergy New Orleans has an exclusive right to file a plan of reorganization until November 15, 2006. Financial Guaranty Insurance Company (FGIC), the insurer of two series totaling $75 million of Entergy New Orleans' first mortgage bonds, filed a motion to terminate the exclusive period within which Entergy New Orleans has an exclusive right to file and solicit acceptances of a plan of reorganization. FGIC asks the court to allow itself or other stakeholders the right to file an alternative and competing plan of reorganization and to solicit acceptances for such a proposed plan. FGIC's motion to terminate exclusivity is set for hearing on November 15, 2006.

The plan of reorganization reflects Entergy New Orleans' continuing effort to work with federal, state, and local authorities to resolve the bankruptcy in a manner that allows Entergy New Orleans' customers to be served by a financially viable entity as required by law. The plan of reorganization also provides full compensation to Entergy New Orleans' creditors whose claims are allowed by the bankruptcy court. Conditions precedent proposed in the plan of reorganization, as currently filed, before it can become effective include:

6

In addition, key factors that will continue to influence the timing and outcome of Entergy New Orleans' recovery efforts include the level of economic recovery of New Orleans and the number of customers that return to New Orleans, including the timing of their return. Entergy New Orleans currently estimates that approximately 85,000 electric customers and 65,000 gas customers have returned and are taking service. Prior to Hurricane Katrina, Entergy New Orleans had approximately 190,000 electric customers and 145,000 gas customers.

The bankruptcy judge set a date of April 19, 2006 by which creditors with prepetition claims against Entergy New Orleans, with certain exceptions, had to file their proofs of claim in the bankruptcy case. Approximately 550 claims, including amending claims, have been filed thus far in Entergy New Orleans' bankruptcy proceeding. Entergy New Orleans is currently analyzing the accuracy and validity of the claims filed, and has begun seeking withdrawal or modification of claims or objecting to claims with which it disagrees. Several of the filed claims have been withdrawn. Entergy New Orleans currently estimates that the pre-petition claims that will be allowed in the bankruptcy case will approximate the pre-petition liabilities that have been classified as liabilities subject to compromise in Entergy New Orleans' Balance Sheet as of September 30, 2006. The plan of reorganization proposes to pay the third party pre-petition accounts payable in full in cash, to issue two-year notes in satisfaction of the affiliate pre-petition accounts payable, and proposes that the first mortgage bonds will remain outstanding with their current maturity dates and interest terms. The plan of reorganization proposes that Entergy New Orleans' preferred stock will also remain outstanding on its current dividend terms.

Municipalization is one potential outcome of Entergy New Orleans' recovery effort that may be pursued by a stakeholder or stakeholders, either in the reorganization process or after Entergy New Orleans exits from bankruptcy. In June 2006, the Louisiana Legislature passed a law that establishes a governance structure for a public power authority, if municipalization of Entergy New Orleans' utility business is pursued. Entergy New Orleans' settlement of its formula rate plan and storm cost and reserve rider proceedings, discussed further below, provides that Entergy New Orleans will work with the City Council to seek an exception to the Stafford Act that will afford Stafford Act protections to Entergy New Orleans if another catastrophic event affects Entergy New Orleans. The Stafford Act provides for restoration funding from the federal government for municipal utilities, but does not allow such funding for investor-owned utilities like Entergy New Orleans.

Since the filing of the bankruptcy proceedings, Entergy New Orleans had not been able to declare and pay dividends on its 4.75% preferred stock for three quarters. As discussed further in the Form 10-K, if dividends with respect to the 4.75% preferred stock are not paid for four quarters, the holders of these shares have the right to elect a majority of the Entergy New Orleans board of directors.  Entergy New Orleans filed a motion in the bankruptcy court seeking authority to recommence paying dividends to the holders of the 4.75% preferred shares. After a hearing on the motion on

 

7

 

 May 3, 2006, the court granted Entergy New Orleans the authority to pay dividends to the holders of the 4.75% preferred shares, beginning with the dividend due on July 1, 2006, and thereafter, unless objections are filed by creditors forty-five days in advance of a dividend payment date. If any objections are filed, the matter would be heard by the bankruptcy court. Entergy New Orleans declared and paid the dividends due on July 1 and October 1, 2006, and intends to declare and pay the dividends on the 4.75% preferred shares each quarter pending resolution of its plan of reorganization.

As discussed in the Form 10-K, as a result of the Entergy New Orleans bankruptcy proceeding, Entergy deconsolidated Entergy New Orleans for financial reporting purposes retroactive to January 1, 2005. Because Entergy owns all of the common stock of Entergy New Orleans, this change will not affect the amount of net income Entergy records resulting from Entergy New Orleans' operations for any current or prior period, but will result in Entergy New Orleans' net income or loss being presented as "Equity in earnings of unconsolidated equity affiliates" rather than its results being included in each individual income statement line item, as is the case for periods prior to 2005.

Results of Operations

Third Quarter 2006 Compared to Third Quarter 2005

Following are income statement variances for Utility, Non-Utility Nuclear, Parent & Other business segments, and Entergy comparing the third quarter 2006 to the third quarter 2005 showing how much the line item increased or (decreased) in comparison to the prior period:

 


Utility

 

Non-Utility
Nuclear

 

Parent & Other


Entergy

(In Thousands)

               

3rd Quarter 2005 Consolidated Net Income (Loss)

 

$304,459  

 

$69,253  

 

($17,324)

$356,388 

Net revenue (operating revenue less fuel expense,
purchased power, and other regulatory charges
(credits) - net)

 



107,707 



43,381 



(7,384)



143,704 

Other operation and maintenance expenses

 

94,128 

12,891 

(6,510)

100,509 

Taxes other than income taxes

 

35,750 

26 

(966)

34,810 

Depreciation

 

8,615 

6,618 

(406)

14,827 

Other income

 

(15,625)

34,736 

17,566 

36,677 

Interest charges

 

5,275 

2,356 

5,509 

13,140 

Other expenses

 

1,369 

2,105 

16 

3,490 

Discontinued operations (net-of-tax)

 

6,058 

6,058 

Income taxes

 

(44,585)

16,476 

8,466 

(19,643)

3rd Quarter 2006 Consolidated Net Income (Loss)

 

$295,989  

 

$106,898  

 

($7,193)

$395,694 

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

8

Net Revenue

Utility

Following is an analysis of the change in net revenue, which is Entergy's measure of gross margin, comparing the third quarter of 2006 to the third quarter of 2005.

  

 

Amount

  

 

(In Millions)

 

 

 

3rd Quarter 2005 net revenue

 

$1,191.6 

Base revenues/Attala cost deferral

 

45.0 

Price applied to unbilled electric sales

 

37.9 

Volume/weather

 

30.0 

Pass-through rider revenue

 

27.4 

Purchased power capacity

 

(15.9)

Net wholesale

 

(11.6)

Other

 

(5.1)

3rd Quarter 2006 net revenue

 

$1,299.3 

The base revenues variance resulted primarily from increases effective October 2005 in the Louisiana jurisdiction of Entergy Gulf States for the 2004 formula rate plan filing and the annual revenue requirement related to the purchase of power from the Perryville generating station, and increases in the Texas jurisdiction of Entergy Gulf States related to an incremental purchased capacity recovery rider that began in December 2005 and a transition to competition rider that began in March 2006. The Attala cost deferral variance resulted from deferred under-recovered Attala power plant costs at Entergy Mississippi that will be recovered through the power management rider. The net income effect of the Attala cost deferral is partially offset by Attala costs in other operation and maintenance expenses, depreciation expense, and taxes other than income taxes.

The price applied to unbilled electric sales variance is due to higher base rates and the exclusion in 2006 of the fuel cost component in the calculation of the price applied to unbilled sales. Effective January 1, 2006, the fuel cost component is no longer included in the unbilled revenue calculation at Entergy Louisiana and the Louisiana jurisdiction at Entergy Gulf States, which is in accordance with regulatory treatment. Entergy expects that the effect of this factor will be a decrease in net revenue of approximately $30 million for its annual results for 2006. See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates " herein.

The volume/weather variance resulted primarily from an increase in electricity usage, including increased usage during the unbilled sales period. Billed usage increased a total of 3% compared to the third quarter of 2005.

The pass-through rider revenue variance is due to a change in 2006 in the accounting for city franchise tax revenues in Arkansas as directed by the APSC. The change results in an increase in rider revenue with a corresponding increase in taxes other than income taxes, resulting in no effect on net income.

The purchased power capacity variance is primarily due to higher capacity charges and new purchased power contracts in 2006. A portion of the increase is due to the amortization of deferred capacity costs and is offset in base revenues due to base rate increases implemented to recover incremental deferred and ongoing purchased power capacity charges, as discussed above.

The net wholesale variance is primarily due to an October 2006 FERC order requiring Entergy Arkansas to make a refund to a coal plant co-owner as a result of a contract dispute . Refer to Note 2 to the consolidated financial statements for further discussion of the FERC's decision.

9

Non-Utility Nuclear

Net revenue increased for Non-Utility Nuclear primarily due to higher pricing in its contracts to sell power. Also contributing to the increase in revenues was increased generation in 2006 due to a power uprate completed since the third quarter of 2005 and fewer outages. Following are key performance measures for Non-Utility Nuclear for the third quarters of 2006 and 2005:

 

2006

 

2005

 

 

 

 

Net MW in operation at September 30

 

4,200

 

4,105

Average realized price per MWh

 

$45.35

 

$42.58

Generation in GWh for the quarter

 

9,028

 

8,474

Capacity factor for the quarter

 

99%

 

95%

Other Operation and Maintenance Expenses

Other operation and maintenance expenses increased for the Utility from $326 million in 2005 to $420 million in 2006 primarily due to the following:

Taxes Other Than Income Taxes

Taxes other than income taxes increased for the Utility from $82 million for the third quarter of 2005 to $118 million for the third quarter of 2006 primarily due to an increase in city franchise taxes in Arkansas due to a change in 2006 in the accounting for city franchise tax revenues as directed by the APSC. The change results in an increase in taxes other than income taxes with a corresponding increase in rider revenue, resulting in no effect on net income. Also contributing to the increase was higher franchise tax expense at Entergy Gulf States as a result of higher gross revenues.

Other Income

Other income increased for Non-Utility Nuclear primarily due to miscellaneous income of $27.0 million ($16.6 million net-of-tax) resulting from a reduction in the decommissioning liability for a plant as a result of revised decommissioning costs and changes in assumptions regarding the timing of when decommissioning of a plant will begin.

Income Taxes

The effective income tax rates for the third quarters of 2006 and 2005 were 33.8% and 37.9%, respectively. The difference in the effective income tax rate for the third quarter of 2006 versus the federal statutory rate of 35.0% is primarily due to the flow-through of a pension item and the favorable resolution of a tax audit issue, partially offset by state income taxes. The difference in the effective income tax rate for the third quarter of 2005 versus the federal statutory rate of 35.0% is primarily due to state income taxes and book and tax differences related to utility plant items, partially offset by investment tax credit amortization.

 

10

 

Nine Months Ended September 30, 2006 Compared to Nine Months Ended September 30, 2005

Following are income statement variances for Utility, Non-Utility Nuclear, Parent & Other business segments, and Entergy comparing the nine months ended September 30, 2006 to the nine months ended September 30, 2005 showing how much the line item increased or (decreased) in comparison to the prior period:

 


Utility

 

Non-Utility
Nuclear

 

Parent & Other


Entergy

(In Thousands)

               

2005 Consolidated Net Income

 

$617,745  

 

$205,495  

 

$4,075 

$827,315 

Net revenue (operating revenue less fuel expense,
purchased power, and other regulatory credits - net)

 


134,776 


98,262 


22,566 


255,604 

Other operation and maintenance expenses

 

105,277 

30,886 

4,636 

140,799 

Taxes other than income taxes

 

40,393 

4,105 

(852)

43,646 

Depreciation

 

10,482 

8,794 

(1,058)

18,218 

Other income

 

4,851 

19,839 

(3,923)

20,767 

Interest charges

 

20,278 

(993)

30,521 

49,806 

Other expenses

 

2,930 

4,420 

49 

7,399 

Discontinued operations (net-of-tax)

 

21,116 

21,116 

Income taxes

 

(51,452)

24,578 

4,872 

(22,002)

2006 Consolidated Net Income

 

$629,464  

 

$251,806  

 

$5,666 

$886,936 

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

Net Revenue

Utility

Following is an analysis of the change in net revenue, which is Entergy's measure of gross margin, comparing the nine months ended September 30, 2006 to the nine months ended September 30, 2005.

  

 

Amount

  

 

(In Millions)

 

 

 

2005 net revenue

 

$3,164.5 

Base revenues/Attala cost deferral

 

99.0 

Volume/weather

 

40.0 

Pass-through rider revenue

 

27.4 

Fuel recovery

 

23.6 

Transmission revenue

 

15.5 

Storm cost recovery

 

 7.3 

Price applied to unbilled electric sales

 

 (57.9)

Net wholesale

 

(12.3)

Other

 

 (7.8)

2006 net revenue

 

$3,299.3 

11

The base revenues variance resulted primarily from increases effective October 2005 in the Louisiana jurisdiction of Entergy Gulf States for the 2004 formula rate plan filing and the annual revenue requirement related to the purchase of power from the Perryville generating station, and increases in the Texas jurisdiction of Entergy Gulf States related to an incremental purchased capacity recovery rider that began in December 2005 and a transition to competition rider that began in March 2006. The Attala cost deferral variance resulted from deferred under-recovered Attala power plant costs at Entergy Mississippi that will be recovered through the power management rider. The net income effect of the Attala cost deferral is partially offset by Attala costs in other operation and maintenance expenses, depreciation expense, and taxes other than income taxes.

The volume/weather variance resulted primarily from increased electricity usage, including the effect of more favorable weather on billed sales, compared to the same period in 2005 and an increase in usage during the unbilled period. Billed usage increased a total of 2% in the residential and commercial sectors.

The pass-through rider revenue variance is due to a change in 2006 in the accounting for city franchise tax revenues in Arkansas as directed by the APSC. The change results in an increase in rider revenue with a corresponding increase in taxes other than income taxes, resulting in no effect on net income.

The fuel recovery variance resulted primarily from adjustments of fuel clause recoveries in Entergy Gulf States' Louisiana jurisdiction, the under-recovery in 2005 of fuel costs from retail customers, and increased recovery in 2006 of fuel costs. The increase was partially offset by the Entergy Arkansas energy cost recovery true-up made in the first quarter of 2005.

The transmission revenue variance is primarily due to new transmission customers in 2006. Also contributing to the increase was an increase in rates effective June 2006.

The storm cost recovery variance is due to the return earned on the interim recovery of storm-related costs at Entergy Louisiana and the Louisiana jurisdiction of Entergy Gulf States in early-2006 as allowed by the LPSC.

The price applied to unbilled sales variance is due to the exclusion in 2006 of the fuel cost component in the calculation of the price applied to unbilled sales. Effective January 1, 2006, the fuel cost component is no longer included in the unbilled revenue calculation at Entergy Louisiana and the Louisiana jurisdiction at Entergy Gulf States, which is in accordance with regulatory treatment. Entergy expects that the effect of this factor will be a decrease in net revenue of approximately $30 million for its annual results for 2006. See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates " herein.

The net wholesale variance is primarily due to an October 2006 FERC order requiring Entergy Arkansas to make a refund to a coal plant co-owner as a result of a contract dispute. Refer to Note 2 to the consolidated financial statements for further discussion of the FERC's decision.

Non-Utility Nuclear

Net revenue increased for Non-Utility Nuclear primarily due to higher pricing in its contracts to sell power. Also contributing to the increase in revenues was increased generation in 2006 due to power uprates at certain plants completed in 2005 and 2006 and fewer refueling outages in 2006. Following are key performance measures for Non-Utility Nuclear for the nine months ended September 30, 2006 and 2005:

 

 

2006

 

2005

 

 

 

 

 

Net MW in operation at September 30

 

4,200

 

4,105

Average realized price per MWh

 

$44.58

 

$42.26

Generation in GWh for the period

 

26,018

 

24,896

Capacity factor for the period

 

95%

 

93%

12

Parent & Other

Net revenue increased for Parent & Other primarily due to the $14.1 million gain ($8.6 million net-of-tax) realized on the sale of the non-nuclear wholesale asset business' remaining interest in a power development project.

Other Operation and Maintenance Expenses

Other operation and maintenance expenses increased for the Utility from $1.1 billion in 2005 to $1.2 billion in 2006 primarily due to the following:

  • an increase of $23 million in payroll and benefits costs;
  • the receipt in 2005 of proceeds of $16 million from a settlement, which is discussed in " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Central States Compact Claim " in the Form 10-K;
  • an increase of $14 million due to the expensing of plant maintenance and distribution costs in 2006 versus the deferral or capitalization of storm costs in 2005;
  • an increase of $12 million related to storm reserves. This increase does not include costs associated with Hurricanes Katrina and Rita;
  • an increase of $12 million in nuclear costs as a result of higher NRC fees, security costs, labor-related costs, and a non-refueling plant outage at Entergy Gulf States in February 2006;
  • an increase of $11 million in customer service support costs due to an increase in contract costs and an increase in customer write-offs; and
  • an increase of $10 million in fossil costs due to the purchase of the Attala plant in January 2006 and the Perryville generating station coming online in July 2005.

Other operation and maintenance expenses increased for Non-Utility Nuclear from $438 million in 2005 to $469 million in 2006 primarily due to the timing of refueling outages, and increased benefit and insurance costs.

Taxes Other Than Income Taxes

Taxes other than income taxes increased for the Utility from $240 million in 2005 to $280 million in 2006 primarily due to an increase in city franchise taxes in Arkansas due to a change in 2006 in the accounting for city franchise tax revenues as directed by the APSC. The change results in an increase in taxes other than income taxes with a corresponding increase in rider revenue, resulting in no effect on net income. Also contributing to the increase was higher franchise tax expense at Entergy Gulf States as a result of higher gross revenues.

Interest Charges

Interest charges increased for the Utility and Parent & Other primarily due to additional borrowing to fund the significant storm restoration costs associated with Hurricanes Katrina and Rita.

Discontinued Operations

Income from discontinued operations increased primarily due to the $17.1 million gain (net-of-tax) on the sale of the retail electric portion of the Competitive Retail Services business operating in the ERCOT region of Texas.

Income Taxes

The effective income tax rates for the nine months ended September 30, 2006 and 2005 were 33.6% and 35.7%, respectively. The difference in the effective income tax rate for the nine months ended September 30, 2006 versus the federal statutory rate of 35.0% is primarily due to the flow-through of a pension item, the recognition of an income tax benefit related to ANO 1 steam generator removal cost, and the favorable resolution of a tax audit issue, partially offset by state income taxes. The difference in the effective income tax rate for the nine months ended September 30, 2005

 

13

 

 versus the federal statutory rate of 35.0% is primarily due to state income taxes and book and tax differences related to utility plant items, partially offset by tax benefits from the American Jobs Creation Act of 2004, investment tax credit amortization, and a downward revision in the estimate of federal income tax expense related to tax depreciation.

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.

Debtor-in-Possession Credit Facility

See the Form 10-K for a discussion of the Entergy New Orleans debtor-in-possession (DIP) credit facility between Entergy New Orleans as borrower and Entergy Corporation as lender. Following is an update to that discussion.

As discussed in the Form 10-K, the bankruptcy court issued its order in December 2005 giving final approval for the $200 million DIP credit facility, and the indenture trustee for Entergy New Orleans' first mortgage bonds appealed the order. On March 29, 2006 the bankruptcy court approved a settlement among Entergy New Orleans, Entergy Corporation, and the indenture trustee, and the indenture trustee dismissed its appeal. As of September 30, 2006, Entergy New Orleans had approximately $32 million of outstanding borrowings under the DIP credit facility.

As discussed in the Form 10-K, borrowings under the DIP credit facility are due in full, and the agreement will terminate, at the earliest of several times or events, which included August 23, 2006. Entergy Corporation and Entergy New Orleans have agreed to an amendment to the DIP credit agreement that extends the August 23, 2006 maturity date to August 23, 2007, and the bankruptcy court approved this amendment.

Capital Structure

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

 

 

September 30,
2006

 

December 31,
2005

 

 

 

 

 

Net debt to net capital

 

48.3%

 

51.5%

Effect of subtracting cash from debt

 

2.1%

 

1.6%

Debt to capital

 

50.4%

 

53.1%

Net debt consists of debt less cash and cash equivalents. Debt consists of notes payable, capital lease obligations, preferred stock with sinking fund, and long-term debt, including the currently maturing portion. Capital consists of debt, common shareholders' equity, and preferred stock without sinking fund. Net capital consists of capital less cash and cash equivalents. Entergy 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's financial condition.

As discussed in the Form 10-K, Entergy Corporation has in place two separate revolving credit facilities, a five-year credit facility and a three-year credit facility. The five-year credit facility expires in May 2010 and the three-year facility expires in December 2008. Entergy can issue letters of credit against the total borrowing capacity of both credit facilities. Following is a summary of the borrowings outstanding and capacity available under these facilities as of September 30, 2006:

14


Facility

 


Capacity

 


Borrowings

 

Letters
of Credit

 

Capacity
Available

   

(In Millions)

                 

5-Year Facility

 

$2,000 

 

$495 

 

$94 

 

$1,411

3-Year Facility

 

$1,500 

 

$- 

 

$-  

 

$1,500

Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, and Entergy Mississippi each has credit facilities available as of September 30, 2006 as follows:


Company

 


Expiration Date

 

Amount of
Facility

 

Amount Drawn as of
September 30, 2006

 

 

 

 

 

 

 

Entergy Arkansas

 

April 2007

 

$85 million

 

-

Entergy Gulf States

 

February 2011

 

$50 million (a)

 

-

Entergy Mississippi

 

May 2007

 

$30 million (b)

 

-

Entergy Mississippi

 

May 2007

 

$20 million (b)

 

-

(a)

The credit facility allows Entergy Gulf States to issue letters of credit against the borrowing capacity of the facility. As of September 30, 2006, $1.4 million in letters of credit had been issued.

(b)

Borrowings under the Entergy Mississippi facilities may be secured by a security interest in its accounts receivable.

See Note 4 to the consolidated financial statements for additional discussion of Entergy's credit facilities.

Capital Expenditure Plans and Other Uses of Capital

See the table in the Form 10-K under " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources - Capital Expenditure Plans and Other Uses of Capital ," which sets forth the amounts of planned construction and other capital investments by operating segment for 2006 through 2008. Following are updates to that discussion:

In July 2006, Entergy's Non-Utility Nuclear business reached an agreement to purchase Consumers Energy Company's 798 MW Palisades nuclear energy plant located near South Haven, Michigan for $380 million. Entergy's Non-Utility Nuclear business will acquire the plant, nuclear fuel, and other assets. In the near-term, Entergy intends to finance the acquisition through borrowings from Entergy Corporation's revolving credit facilities. As part of the purchase, Entergy's Non-Utility Nuclear business also executed a 15-year purchased power agreement with Consumers Energy for 100% of the plant's output, excluding any future uprates. Entergy's Non-Utility Nuclear business will assume responsibility for eventual decommissioning of the plant. Consumers Energy will retain $200 million of the current $566 million Palisades decommissioning trust fund balance, and Entergy may return approximately $100 million more of the trust fund to Consumers Energy depending upon a pending tax ruling. Also as part of the transaction, Consumers Energy will pay Entergy's Non-Utility Nuclear business $30 million to accept responsibility for spent fuel at the decommissioned Big Rock nuclear plant, which is located near Charlevoix, Michigan. Management expects to close the transaction in the second quarter 2007, pending the approvals of the NRC, the FERC, the Michigan Public Service Commission, and other regulatory agencies.

Entergy is developing its capital plan for 2007 through 2009 and currently anticipates making $5.2 billion in capital investments during that period, including approximately $2.5 billion ($2.3 billion for Utility and $0.2 billion for Non-Utility Nuclear) for maintenance of Entergy's existing assets. The remaining $2.7 billion ($1.9 billion for Utility and $0.8 billion for Non-Utility Nuclear) is associated with specific investments such as the pending Palisades acquisition, transmission upgrades, dry cask storage and license renewal projects at certain nuclear sites, environmental compliance spending, NYPA value sharing costs and other investments, such as potential opportunities through the Utility's supply plan initiatives that support its ability to meet load growth.

 

15

The Pension Protection Act of 2006

The Pension Protection Act of 2006 was signed by the President on August 17, 2006. The intent of the legislation is to require companies to fund 100% of their pension liability; and then for companies to fund, on a going-forward basis, an amount generally estimated to be the amount that the pension liability increases each year due to an additional year of service by the employees eligible for pension benefits. The legislation requires that funding shortfalls be eliminated by companies over a seven-year period, beginning in 2008.

The Pension Protection Act also extended the provisions of the Pension Funding Equity Act that would have expired in 2006 had the Pension Protection Act not been enacted, which increased the allowed discount rate used to calculate the pension funding liability. Entergy is in the process of evaluating the effects of the new legislation, but expects that the implementation of the Pension Protection Act will not result in annual pension contributions going-forward that are materially higher than the levels required in 2005 and 2006.

Cash Flow Activity

As shown in Entergy's Statements of Cash Flows, cash flows for the nine months ended September 30, 2006 and 2005 were as follows:

 

 

2006

 

2005

 

 

(In Millions)

 

 

 

 

 

Cash and cash equivalents at beginning of period

 

$583 

 

$620 

 

 

 

 

 

Effect of deconsolidating Entergy New Orleans in 2005

(8)

Cash flow provided by (used in):

 

 

 

 

 

Operating activities

 

 2,257 

 

1,107 

 

Investing activities

 

(1,395)

 

(1,204)

 

Financing activities

 

(699)

 

 84 

Effect of exchange rates on cash and cash equivalents

(1)

(1)

Net increase (decrease) in cash and cash equivalents

 

162 

 

(14)

 

 

 

 

 

Cash and cash equivalents at end of period

 

$745 

 

$598 

Operating Activities

Entergy's cash flow provided by operating activities increased by $1,150 million for the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005 primarily due to the following activity:

Entergy Corporation received a $344 million income tax refund (including $71 million attributable to Entergy New Orleans) as a result of net operating loss carryback provisions contained in the Gulf Opportunity Zone Act of 2005, as discussed in the Form 10-K. In accordance with Entergy's intercompany tax allocation agreement, $273 million of the refund was distributed to the Utility (including Entergy New Orleans) in April 2006, with the remainder distributed primarily to Non-Utility Nuclear.

16

Investing Activities

Net cash used in investing activities increased by $191 million for the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005 primarily due to the following activity:

The increase was partially offset by:

Financing Activities

Net cash used in financing activities was $699 million for the nine months ended September 30, 2006 compared to net cash flow provided by financing activities of $84 million for the nine months ended September 30, 2005. Following is a description of the significant financing activity occurring during the first nine months of 2006 and 2005:

17

Significant Factors and Known Trends

See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends " in the Form 10-K for discussions of rate regulation, federal regulation, market and credit risks, utility restructuring, and nuclear matters. Following are updates to the information provided in the Form 10-K.

State and Local Rate Regulation

See the Form 10-K for the chart summarizing material rate proceedings. Following are updates to that chart. See also Hurricanes Katrina and Rita above for updates regarding storm cost recovery proceedings.

Entergy Arkansas

In March 2006, Entergy Arkansas filed with the APSC its annual redetermination of the energy cost rate for application to the period April 2006 through March 2007. The filed energy cost rate of $0.02827 per kWh was proposed to replace the interim rate of $0.01900 per kWh that had been in place since October 2005. The interim energy cost rate is discussed in Note 2 to the financial statements in the Form 10-K, along with the investigation that the APSC commenced concerning Entergy Arkansas' interim energy cost rate. The increase in the energy cost rate is due to increases in the cost of purchased power primarily due to the natural gas cost increase and the effect that Hurricanes Katrina and Rita had on market conditions, increased demand for purchased power during the ANO 1 refueling and steam generator replacement outage in the fall of 2005, and coal plant generation curtailments during off-peak periods due to railroad delivery problems.

On March 31, 2006, the APSC suspended implementation of the $0.02827 per kWh energy cost rate, and ordered that the $0.01900 per kWh interim rate remain in effect pending the APSC proceedings on the energy cost recovery filings. The APSC also extended its investigation into Entergy Arkansas' interim energy cost rate to cover the costs included in Entergy Arkansas' March 2006 filing. The extended investigation did not identify new issues in addition to the four issues listed in the Form 10-K and covers the same time period. On April 7, 2006, the APSC issued a show cause order in the investigation proceeding that ordered Entergy Arkansas to file a cost of service study by June 8, 2006. The order also directed Entergy Arkansas to file testimony to support the cost of service study, to support the $0.02827 per kWh cost rate, and to address the general topic of elimination of the energy cost recovery rider.

In June 2006, Entergy Arkansas filed a motion with the APSC seeking again to implement the redetermined energy cost rate of $0.02827 per kWh. After a hearing, the APSC approved Entergy Arkansas' request and the redetermined rate was implemented in July 2006, subject to refund pending the outcome of the APSC energy cost recovery investigation. Because of the delay in implementing the redetermined energy cost rate, Entergy Arkansas estimated in its motion that $46 million of energy costs would remain under-recovered at December 31, 2006.

On June 7, 2006, Entergy Arkansas filed a cost of service study and testimony supporting the redetermined energy cost rate and testimony addressing the prospective elimination of the energy cost recovery rider as ordered by the APSC. A hearing was held in the APSC energy cost recovery investigation on October 12, 2006 and post-hearing briefs were filed by Entergy Arkansas, the APSC General Staff, the Arkansas Attorney General, and the Arkansas Electric Energy Consumers. No party recommended termination of the energy cost recovery rider in the fuel cost investigation proceeding. The timing of a decision in this proceeding is uncertain.

In August 2006, Entergy Arkansas filed with the APSC a request for a change in base rates. Entergy Arkansas requested a general base rate increase of $150 million (using an ROE of 11.25%), as well as recovery of FERC-allocated costs pursuant to the FERC decision on the System Agreement. Entergy Arkansas also requested a capacity management rider to recover incremental capacity costs. A procedural schedule has been established with hearings expected to begin in April 2007.

See "System Agreement Litigation" herein for a discussion of Entergy's compliance filing in that proceeding. If the FERC approves the compliance

 

18

 

tariff as filed, then payments under that tariff will be classified as energy costs, which would then be included in setting the retail energy cost rate as part of the normal working of the energy cost recovery rider.  As noted above, the APSC has given notice that it is considering the prospective elimination of the energy cost recovery rider.  Therefore, Entergy Arkansas proposed in the August 2006 base rate case an alternative to the energy cost recovery rider for recovery of the costs allocated to it as a result of the System Agreement litigation should the energy cost recovery rider be lawfully terminated by the APSC.  A separate exact recovery rider, similar to the energy cost recovery rider, would ensure that Entergy Arkansas customers pay only the amount allocated by the FERC.

Entergy Gulf States-Louisiana

In January 2006, Entergy Gulf States filed with the LPSC its gas rate stabilization plan. The filing showed a revenue deficiency of $4.1 million based on an ROE mid-point of 10.5%. On May 1, 2006, Entergy Gulf States implemented a $3.5 million rate increase pursuant to an uncontested agreement with the LPSC Staff.

In March 2006, the LPSC approved an uncontested stipulated settlement in Entergy Gulf States' formula rate plan filing for the 2004 test year. The settlement includes a revenue requirement increase of $36.8 million and calls for Entergy Gulf States to apply a refund liability of $0.7 million to capacity deferrals. The refund liability pertained to the periods 2004-2005 as well as the interim period in which a $37.2 million revenue increase was in place.

In May 2006, Entergy Gulf States made its formula rate plan filing with the LPSC for the 2005 test year. Entergy Gulf States modified the filing in August 2006 to reflect an 11.1% return on equity which is within the allowed bandwidth. The modified filing includes a formula rate plan increase of $17.2 million which provides for interim recovery of storm costs from Hurricanes Katrina and Rita and recovery of LPSC-approved incremental deferred and ongoing capacity costs. The increase was implemented, subject to refund, with the first billing cycle of September 2006.

Entergy Gulf States -Texas

As discussed in Note 2 to the consolidated financial statements in the Form 10-K, in August 2005, Entergy Gulf States filed with the PUCT an application for recovery of its transition to competition costs. Entergy Gulf States requested recovery of $189 million in transition to competition costs through implementation of a 15-year rider to be effective no later than March 1, 2006. The $189 million represents transition to competition costs Entergy Gulf States incurred from June 1, 1999 through June 17, 2005 in preparing for competition in its Texas service area, including attendant AFUDC, and all carrying costs projected to be incurred on the transition to competition costs through February 28, 2006. The $189 million is before any gross-up for taxes or carrying costs over the 15-year recovery period. Entergy Gulf States reached a unanimous settlement agreement on all issues with the active parties in the transition to competition cost recovery case. The agreement allows Entergy Gulf States to recover $14.5 million per year in transition to competition costs over a 15-year period. Entergy Gulf States implemented interim rates based on this revenue level on March 1, 2006. The PUCT approved the settlement agreement in June 2006.

Entergy Louisiana

In May 2006, Entergy Louisiana made its formula rate plan filing with the LPSC for the 2005 test year. Entergy Louisiana modified the filing in August 2006 to reflect a 9.45% return on equity which is within the allowed bandwidth. The modified filing includes an increase of $24 million for interim recovery of storm costs from Hurricanes Katrina and Rita and a $120 million rate increase to recover LPSC-approved incremental deferred and ongoing capacity costs. The filing requested recovery of approximately $50 million for the amortization of capacity deferrals over a three-year period, including carrying charges, and approximately $70 million for ongoing capacity costs. The increase was implemented, subject to refund, with the first billing cycle of September 2006. Comments were provided by the LPSC Staff, which Entergy Louisiana is currently reviewing. Entergy Louisiana subsequently updated its formula rate plan rider to reflect adjustments proposed by the LPSC Staff with which it agrees. The adjusted return on equity of 9.56% remains within the allowed bandwidth. Ongoing and deferred incremental capacity costs were reduced to $119 million. The updated formula rate plan rider was implemented, subject to refund, with the first billing cycle of October 2006.

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Entergy Mississippi

In March 2006, Entergy Mississippi made its annual scheduled formula rate plan filing with the MPSC.  The filing was amended by an April 2006 filing.  The amended filing showed that an increase of $3.1 million in electric revenues is warranted.  The MPSC has approved a settlement providing for a $1.8 million rate increase, which was implemented in August 2006.

Entergy New Orleans

In June 2006, Entergy New Orleans made its annual formula rate plan filings with the City Council.  The filings presented various alternatives to reflect the effect of Entergy New Orleans' lost customers and decreased revenue. Entergy New Orleans' recommended alternative adjusts for lost customers and assumes that the City Council's June 2006 decision to allow recovery of all Grand Gulf costs through the fuel adjustment clause stays in place during the rate-effective period (a significant portion of Grand Gulf costs was previously recovered through base rates).

At the same time as it made its formula rate plan filings, Entergy New Orleans also filed with the City Council a request to implement two storm-related riders. With the first rider, Entergy New Orleans sought to recover the electric and gas restoration costs that it had actually spent through March 31, 2006. Entergy New Orleans also proposed semiannual filings to update the rider for additional restoration spending and also to consider the receipt of CDBG funds or insurance proceeds that it may receive. With the second rider, Entergy New Orleans sought to establish a storm reserve to provide for the risk of another storm.

In October 2006 the City Council approved a settlement agreement that resolves Entergy New Orleans' rate and storm-related rider filings by providing for phased-in rate increases, while taking into account with respect to storm restoration costs the anticipated receipt of CDBG funding as recommended by the Louisiana Recovery Authority. The settlement provides for a 0% increase in electric base rates through December 2007, with a $3.9 million increase implemented in January 2008. Recovery of all Grand Gulf costs through the fuel adjustment clause will continue. Gas base rates will increase by $4.75 million in November 2006, an additional $1.5 million in March 2007, and an additional $4.75 million in November 2007. The settlement calls for Entergy New Orleans to file a base rate case by July 31, 2008. Any storm costs in excess of CDBG funding and insurance proceeds will be addressed in that base rate case. A storm cost recovery rider is authorized but initially set at $0 because of the anticipated receipt of CDBG funding. The settlement also authorizes a $75 million storm reserve for damage from future storms, which will be created over a ten-year period through a storm reserve rider beginning in March 2007. These storm reserve funds will be held in a restricted escrow account.

Federal Regulation

System Agreement Litigation

See the Form 10-K for a discussion of the System Agreement litigation proceedings at the FERC. In April 2006, Entergy filed with the FERC its compliance filing to implement the provisions of the FERC's decision. The filing amends the System Agreement to provide for the calculation of production costs, average production costs, and payments/receipts among the domestic utility companies to the extent required to maintain rough production cost equalization pursuant to the FERC's decision, and makes clear that all payments/receipts will be classified as energy costs. The payments/receipts would be based on calendar year 2006 production costs, with any payments/receipts among the domestic utility companies to be made in twelve equal monthly installments, commencing in June 2007.

Motions to intervene without protest were filed by the City of New Orleans, the MPSC, the Louisiana Energy Users Group, and Occidental Chemical Corporation. Protests to the compliance filing were filed by the APSC, the LPSC, Arkansas Electric Energy Consumers, Inc. (AEEC), and the Arkansas Attorney General (Arkansas AG). Among other things, the LPSC urged the FERC: (1) to require any payments/receipts to

 

20

 

 commence in January 2007, rather than June 2007, and to require such payments to be made in a single lump sum payment, rather than in twelve equal monthly installments, or in the alternative to require a paying utility company to complete all payments within the calendar year following the year in which the disparity occurred; (2) to find that the bandwidth remedy is analogous to a "cost-of-service tariff with deferred billing," as opposed to a prospective remedy, so that a utility company could be required to make a payment based on a previous year's production costs even if such utility company has exited the System Agreement and so that interest would be due on the amount of any payment; and (3) to order interest on any payments to the extent they are not made in a single lump sum amount. In addition to the above issues, the LPSC and the other parties filing protests urged the FERC to require the bandwidth calculation to be set forth in a separate service schedule within the System Agreement, rather than the existing Service Schedule MSS-3 as proposed by Entergy. The APSC's protest urged the FERC to require that the bandwidth formula include all bandwidth payments as a production cost of the paying utility company for the year in which the payment is made, instead of excluding such costs as proposed in the compliance filing. The AEEC, among other things, urges the FERC to segregate the capacity and energy cost components of any bandwidth payments/receipts. The domestic utility companies responded to the issues raised in the protests and urged the FERC to approve the compliance filing as submitted by Entergy. The LPSC filed a reply to Entergy's response reasserting its previous positions and alleging, among other things, that Entergy was trying to delay the bandwidth payment in an effort to protect purported excess profits at Entergy Arkansas.

Separately, in July 2006 the LPSC filed with the FERC a Motion for Summary Disposition on the same issues that the LPSC had raised in its protests to the compliance filing. The domestic utility companies filed an answer urging the FERC to reject the LPSC's Motion for Summary Disposition and asking the FERC for summary disposition of several issues in favor of the domestic utility companies' positions.

The FERC's decision in the System Agreement proceeding is currently pending before the United States Court of Appeals for the D.C. Circuit. The parties to the proceeding reached agreement on a proposed briefing schedule that would result in the completion of briefing during the first half of 2007. The proposed briefing schedule has been submitted to the Court of Appeals.

The FERC's decision would reallocate total production costs of the domestic utility companies whose relative total production costs expressed as a percentage of Entergy System average production costs are outside an upper or lower bandwidth. This would be accomplished by payments from domestic utility companies whose production costs are more than 11% below Entergy System average production costs to domestic utility companies whose production costs are more than the Entergy System average production cost, with payments going first to those domestic utility companies whose total production costs are farthest above the Entergy System average. For purposes of the August 2006 Entergy Arkansas general base rate case filing discussed above in "State and Local Rate Regulation", an assessment of the potential effects of the FERC's June 2005 order, as amended by its December 2005 order on rehearing, was calculated on the basis of a 2006 test year, using a 2006 gas price that consisted of a non-weighted average of twelve months of gas prices calculated as follows: January through May 2006 were actual, volume-weighted monthly averages of day-ahead cash prices as reported by Energy Intelligence Natural Gas Week ; the June 2006 price was the First of the Month Index price as reported by Platts Inside FERC's Gas Market Report ; the July 2006 price was the 5/31/06 NYMEX Henry Hub settlement price; and August through December 2006 were 30 calendar-day rolling averages as of May 31, 2006 of forward NYMEX Henry Hub gas contracts.  For example, the August 2006 price was an average of all the daily NYMEX settlement prices for the August 2006 contract for each trading day from the period 5/2/06 - 5/31/06 inclusive.  A similar calculation was made using the daily settlements of the September 2006 through December 2006 NYMEX contracts to arrive at those monthly prices. This resulted in an average annual gas price of $7.49/mmBtu. If the FERC's June 2005 order, as amended by its December 2005 order on rehearing, becomes final and if an annual average gas price of $7.49/mmBtu occurs for 2006 as assumed, the following potential annual production cost reallocation among the domestic utility companies could result:

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Annual Payments
or (Receipts)

 

(In Millions)

Entergy Arkansas

$284

Entergy Gulf States

($197)

Entergy Louisiana

($59)

Entergy Mississippi

($28)

Entergy New Orleans

$0

If the actual, annual, average natural gas price deviates by $1/mmBtu up or down from the price assumed above, it is expected that Entergy Arkansas' annual payments will change in the same direction by approximately $70 to $80 million.

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

APSC Complaint at the FERC

In June 2006, the APSC filed a complaint with the FERC against Entergy Services as the representative of Entergy Corporation and the domestic utility companies, pursuant to Sections 205, 206 and 207 of the Federal Power Act. The APSC complaint states, "the purpose of the complaint is to institute an investigation into the prudence of Entergy's practices affecting the wholesale rates that flow through its System Agreement." The complaint requests, among other things, that the FERC disallow any costs found to be imprudent, with a refund effective date to be set at the earliest possible time. Specific areas of requested investigation include:

The complaint also requests that the FERC exercise its authority under Section 207 of the FPA to investigate the adequacy of Entergy's transmission system and direct it to make all necessary upgrades to ensure that its transmission facilities provide reliable, adequate and economic service.

In July 2006, the domestic utility companies submitted their answer to the APSC complaint. In their answer, the domestic utility companies acknowledge that while the FERC is the appropriate forum to consider the issues raised in the APSC's complaint, the APSC has provided no probative evidence supporting its allegations and has not met the standards under the Federal Power Act (FPA) to have a matter set for hearing. Under the FPA standards, the APSC must create "serious doubt" as to the propriety of the challenged actions. As indicated in the domestic utility companies' answer, the APSC complaint does not raise a "serious doubt" but instead largely relies on unsupported assertions, many of which have been investigated in other proceedings. In those limited instances when the APSC complaint references "evidence" in an attempt to support its request for a hearing, the "evidence" to which it refers in fact does nothing to support its position but, rather, shows that Entergy has acted prudently. As further indicated in the domestic utility companies' answer, following the issuance of the FERC's System Agreement decision, all of the production costs of the domestic utility companies are now inputs to a formula rate that will result in bandwidth payments among the domestic utility companies in order to roughly equalize production costs. The domestic utility companies' answer further explains that based on well-established

 

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Supreme Court precedent, the FERC has exclusive jurisdiction over all inputs that will be included in the System Agreement bandwidth formula rates filed in compliance with the FERC's System Agreement decision and retail regulators are preempted from taking any action that disturbs the FERC's findings with respect to these production cost inputs and the FERC-determined allocation of production costs among the domestic utility companies. The domestic utility companies believe that their conduct with respect to these issues has been prudent and will vigorously defend such conduct.

Several parties have intervened in the proceeding, including the MPSC, the LPSC, and the City Council. The LPSC's answer and comments in response to the APSC complaint ask the FERC to investigate whether Entergy Arkansas' withdrawal from the System Agreement is fair, just, and reasonable. In September 2006, the domestic utility companies, the APSC, and other intervenors in the proceeding filed responses to the answers and comments submitted by the various intervenors in July 2006. In their responses, the APSC and the LPSC, among others, argue that the FERC need not address at this time its jurisdiction over the matters raised by the complaint and further that the retail regulators are not preempted from exercising jurisdiction over those same production costs that are being considered in the proceeding. In October 2006, the domestic utility companies filed an answer to the other parties' September 2006 comments. In the October 2006 answer, the domestic utility companies explain, among other things, that the FERC must address the jurisdictional issues raised by the parties to the proceeding and that the LPSC's and APSC's view concerning jurisdiction and preemption are inconsistent with federal law and regulation.

APSC System Agreement Investigation

In 2004, the APSC commenced an investigation into whether Entergy Arkansas' continued participation in the System Agreement is in the best interests of its customers. Citing its concerns that the benefits of its continued participation in the current form of the System Agreement have been seriously eroded, in December 2005, Entergy Arkansas submitted its notice that it will terminate its participation in the current System Agreement effective 96 months from December 19, 2005 or such earlier date as authorized by the FERC. Entergy Arkansas indicated, however, that a properly structured replacement agreement could be a viable alternative. In June 2006 the APSC issued an order in its investigation requiring Entergy Arkansas President Hugh McDonald to file testimony in response to several questions involving details of what action Entergy Arkansas or Entergy has taken to insure that Entergy Arkansas' customers are protected from additional costs including those related to the following areas: construction of new generating plants located outside of Arkansas, costs of the Entergy New Orleans bankruptcy, and costs associated with restoration of facilities damaged by Hurricanes Katrina and Rita. Mr. McDonald was also directed to describe actions taken since December 19, 2005 to encourage or persuade the FERC to authorize Entergy Arkansas to exit the Entergy System Agreement sooner than 96 months, and to describe current and future actions related to development of a replacement system agreement. Responsive testimony was filed with the APSC in July and August 2006. A public hearing for the purpose of cross-examination of Mr. McDonald on his testimony and for questioning by the APSC was also conducted in July 2006. There is no further procedural schedule set in this investigation at this time.

MPSC System Agreement Inquiry

In response to an inquiry from the MPSC, Entergy Mississippi advised the MPSC of its view that it would be premature to decide at this time whether to terminate Entergy Mississippi's participation in the current System Agreement. Entergy Mississippi indicated that it would report to the MPSC during the first quarter of 2007 regarding its continuing evaluation of the issues concerning Entergy Mississippi's participation in the current System Agreement.

Independent Coordinator of Transmission (ICT)

In April 2006 the FERC issued an order approving with modification Entergy's ICT proposal filed in May 2005. In its order, the FERC: (1) approved the establishment of the ICT, with modifications; (2) approved Entergy's proposed pricing policy, with modifications; (3) approved the implementation of a weekly procurement process (WPP); and (4) ordered Entergy to submit a compliance filing and an executed contract with the Southwest Power Pool (SPP), the approved ICT, within 60 days of the order. Several parties filed requests for rehearing of the FERC order.

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The proposed modifications include, among other things: (1) Entergy must file with the FERC the criteria used to grant and deny transmission service, including calculating available flowgate capacity; (2) the FERC extended the initial term of the ICT from two years to four years; and Entergy is precluded from terminating the ICT prior to the end of the four-year period; (3) the establishment of a transmission users group that will provide input directly to the ICT on the effectiveness of the ICT Proposal and also will propose to the FERC an appropriate means by which they could be given access to inputs in the process and models under the direction of the ICT; (4) with regard to any dispute between the ICT and Entergy concerning transmission service requests, transmission planning, and interconnection requests, the ICT's position will prevail during the pendency of the dispute resolution; and (5) the WPP must be operational within approximately 14 months of the FERC order or the FERC may reevaluate all approvals to proceed with the ICT. In September 2006, the FERC issued orders that generally denied the requests for rehearing relating to the ICT Proposal and related matters at the FERC. The domestic utility companies filed a request for clarification of two discrete issues arising from the FERC order on rehearing related to the ICT Proposal.

Entergy's domestic utility companies made their compliance filing with the FERC on May 24, 2006, including the executed ICT agreement with SPP. The domestic utility companies informed the FERC that, assuming they have received all required approvals, the domestic utility companies intend to install SPP as the ICT within 30 days of FERC approval of the ICT agreement. Several parties filed protests regarding the domestic utility companies' compliance filing. On October 18, 2006, the FERC accepted the domestic utility companies' compliance filing, with modification, and directed the domestic utility companies to install SPP as the ICT within 30 days of the order. The required changes to the compliance filing include, among others, the elimination of provisions that would have, in certain limited instances, allowed the ICT to be terminated during the initial four-year term. The domestic utility companies were also ordered to file certain additional information with the FERC and to submit the required changes to the compliance filing. The domestic utility companies anticipate installing the ICT within 30 days of the FERC order as directed by the FERC.

The LPSC voted to approve the ICT proposal in July 2006.

Available Flowgate Capacity (AFC) Proceeding

See the Form 10-K for a discussion of previous activity in this proceeding. Following the notification of the potential loss by the domestic utility companies of AFC data, a separate, non-public investigation was initiated by the FERC to review the domestic utility companies' record retention policies and practices. In October 2006, the FERC Office of Enforcement issued an audit report addressing the domestic utility companies' compliance with the FERC's records retention regulations. The audit report notes the following: (i) one instance where the domestic utility companies' treatment of a contract failed to comply with a FERC-imposed record retention period and notification requirement; (ii) one instance where the domestic utility companies temporarily lost an individual record but were subsequently able to reproduce it; (iii) four instances where records were retained for the full period required by the FERC, but may have been inadvertently lost prior to a retention period required by a different agency or the domestic utility companies' internal retention requirements; and (iv) a limited number of instances where the domestic utility companies' internal policies could be improved. The findings and recommendations in the audit report, which were agreed to by the domestic utility companies, represent a consensual resolution of the audit. Although these findings are not indicative of any significant areas of non-compliance, the domestic utility companies believe that the audit staff's recommendations will improve the records retention program and therefore agreed to implement the audit staff's recommendations. Additionally, as previously reported in the Form 10-K, during SPP's independent audit of the AFC process limited instances were identified in which transmission service either was granted when there was insufficient transmission capacity or was not granted when there was sufficient transmission capacity. These instances were self-reported to the FERC enforcement staff. As a result of the domestic utility companies' further review of these transactions on a more detailed basis and after identifying another issue related to the design of the AFC computer software program, the domestic utility companies identified additional instances of incorrectly granting or rejecting transmission service requests. The identified instances now involve less than 1.8% of the total transmission service requests acted on during the period at issue.

 

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 The domestic utility companies also self-reported these additional instances to the FERC enforcement staff.  Although it has not evidenced its intent to do so, among the remedies available to the FERC is the ability to levy fines for these instances. The domestic utility companies are working with FERC enforcement staff to provide additional information related to these instances.

Market and Credit Risks

Commodity Price Risk

Power Generation

As discussed more fully in the Form 10-K, the sale of electricity from the power generation plants owned by Entergy's Non-Utility Nuclear business and Energy Commodity Services business, unless otherwise contracted, is subject to the fluctuation of market power prices. Following is an updated summary of the amount of the Non-Utility Nuclear business' output that is sold forward under physical or financial contracts (2006 represents the remaining quarter of the year):

   

2006

 

2007

 

2008

 

2009

 

2010

Non-Utility Nuclear :

                   

Percent of planned generation sold forward:

                   
 

Unit-contingent

 

34%

 

36%

 

28%

 

24%

 

10%

 

Unit-contingent with guarantee of availability (1)

 

52%

 

42%

 

34%

 

17%

 

11%

 

Firm liquidated damages

 

4%

 

7%

 

4%

 

0%

 

0%

 

Palisades assuming second quarter 2007 closing

 

0%

 

10%

 

17%

 

15%

 

16%

 

Total

 

90%

 

95%

 

83%

 

56%

 

37%

Planned generation (TWh) (including pending Palisades acquisition)

 

9

 

38

 

41

 

41

 

41

Average contracted price per MWh (including pending Palisades acquisition)

 

$41

 

$49

 

$53

 

$56

 

$50

Average contracted price per MWh (excluding pending Palisades acquisition)

 

$41

 

$49

 

$55

 

$60

 

$54

(1)

A sale of power on a unit contingent basis coupled with a guarantee of availability provides for the payment to the power purchaser of contract damages, if incurred, in the event the seller fails to deliver power as a result of the failure of the specified generation unit to generate power at or above a specified availability threshold. All of Entergy's outstanding guarantees of availability provide for dollar limits on Entergy's maximum liability under such guarantees.

Excluding the generation associated with the pending Palisades acquisition, Non-Utility Nuclear's total percent of planned generation sold forward is 94% in 2007, 79% in 2008, 48% in 2009, and 25% in 2010.

See the Form 10-K for a discussion of Non-Utility Nuclear's value sharing agreements with NYPA involving energy sales from the Fitzpatrick and Indian Point 3 power plants and a discussion of the Vermont Yankee PPA price adjustment clause. Non-Utility Nuclear's calculation under the NYPA value sharing agreement shows that Non-Utility Nuclear owes NYPA $0 under that agreement for 2005. NYPA's calculation, under its interpretation of the agreement, shows that $90.5 million is due for 2005. Non-Utility Nuclear believes that its interpretation is correct, and has refused NYPA's demand for $90.5 million. As called for by the value sharing agreement, NYPA has filed a demand for arbitration against the Non-Utility Nuclear subsidiaries that own Fitzpatrick and Indian Point 3 to determine the amount owed, if any, for 2005.

Some of the agreements to sell the power produced by Entergy's Non-Utility Nuclear power plants contain provisions that require an Entergy subsidiary to provide collateral to secure its obligations under the agreements. The Entergy subsidiary will be required to provide collateral based upon the difference between the current market and contracted power prices in the regions where Non-Utility Nuclear sells power. The primary

 

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form of collateral to satisfy these requirements would be an Entergy Corporation guaranty.  Cash and letters of credit are also acceptable forms of collateral.  At September 30, 2006, based on power prices at that time, Entergy had in place as collateral $905 million of Entergy Corporation guarantees for wholesale transactions, including $85 million of guarantees that support letters of credit. The assurance requirement associated with Non-Utility Nuclear is estimated to increase by an amount up to $410 million if gas prices increase $1 per MMBtu in both the short- and long-term markets. In the event of a decrease in Entergy Corporation's credit rating to below investment grade, Entergy will be required to replace Entergy Corporation guarantees with cash or letters of credit under some of the agreements.

In addition to selling the power produced by its plants, the Non-Utility Nuclear business sells installed capacity to load-serving distribution companies in order for those companies to meet requirements placed on them by the ISO in their area. Following is a summary of the amount of the Non-Utility Nuclear business' installed capacity that is currently sold forward, and the blended amount of the Non-Utility Nuclear business' planned generation output and installed capacity that is currently sold forward (2006 represents the remaining quarter of the year):

   

2006

 

2007

 

2008

 

2009

 

2010

Non-Utility Nuclear :

                   

Percent of capacity sold forward:

                   
 

Bundled capacity and energy contracts

 

13%

 

11%

 

11%

 

11%

 

11%

 

Capacity contracts

 

82%

 

64%

 

35%

 

26%

 

9%

 

Palisades assuming second quarter 2007 closing

 

0%

 

10%

 

16%

 

16%

 

16%

 

Total

 

95%

 

85%

 

62%

 

53%

 

36%

Planned net MW in operation (average including pending Palisades acquisition)

 

4,200

 

4,666

 

4,998

 

4,998

 

4,998

Average capacity contract price per kW per month

 

$1.1

 

$1.6

 

$1.2

 

$1.3

 

$1.7

Blended Capacity and Energy (based on revenues)

                   

% of planned generation and capacity sold forward

 

87%

 

92%

 

77%

 

51%

 

30%

Average contract revenue per MWh (including pending Palisades acquisition)

 

$42

 

$50

 

$53

 

$57

 

$51

Average contract revenue per MWh (excluding pending Palisades acquisition)

 

$42

 

$51

 

$56

 

$61

 

$55

Excluding the capacity associated with the pending Palisades acquisition, Non-Utility Nuclear's total percent of planned capacity sold forward is 84% in 2007, 54% in 2008, 44% in 2009, and 23% in 2010. Excluding the generation and capacity associated with the pending Palisades acquisition, Non-Utility Nuclear's blended capacity and energy sold forward (based on revenues) is 91% in 2007, 74% in 2008, 45% in 2009, and 21% in 2010.

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, qualified pension and other postretirement benefits, and other contingencies. Following is an update to that discussion.

Unbilled Revenue

As discussed in Note 10 to the consolidated financial statements, effective January 1, 2006, Entergy Louisiana and the Louisiana portion of Entergy Gulf States reclassified the fuel component of unbilled accounts receivable to deferred fuel and will no longer include the fuel component in their unbilled revenue calculations, which is in accordance with regulatory treatment.

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Recently Issued Accounting Pronouncements

FASB Interpretation No. 48, "Accounting for Uncertainty in Income Taxes" (FIN 48) was issued in July 2006 and is effective for Entergy in the first quarter of 2007. The FASB's objective in issuing this interpretation is to increase comparability among companies in financial reporting of income taxes. FIN 48 establishes a "more-likely-than-not" recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return, but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. Entergy does not expect that the adoption of FIN 48 will materially affect its financial position, results of operations, or cash flows.

In September 2006, FASB issued SFAS 158, "Employers' Accounting for Defined Benefit Pension and Other Postretirement Plans, an amendment of FASB Statements Nos. 87, 88, 106 and 132(R)," to be effective December 31, 2006. SFAS 158 requires employers to recognize the overfunded or underfunded status of a defined benefit postretirement plan as an asset or liability in its balance sheet with the offset recorded to other comprehensive income. Entergy has previously disclosed its funded status in Note 10 to the consolidated financial statements in the Form 10-K. SFAS 158 also requires that changes in that funded status be recorded in other comprehensive income in the period in which the changes occur. Entergy's Utility business, with the exception of the Louisiana jurisdictions which provide for recovery of other postretirement benefit costs on a pay as you go basis, is generally allowed to recover pension and other postretirement benefit costs each period based upon costs calculated under SFAS 87 and SFAS 106. Entergy's analysis, including the regulatory accounting requirements to support recording the majority of the effect of adoption of SFAS 158 as a regulatory asset, is not yet complete.  Entergy does not expect the implementation of this standard, however, to materially affect Entergy's financial position or results of operations.

 

 

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
For the Three and Nine Months Ended September 30, 2006 and 2005
(Unaudited)
                 
    Three Months Ended   Nine Months Ended
    2006   2005   2006   2005
    (In Thousands, Except Share Data)
                 
OPERATING REVENUES                
Domestic electric   $2,761,124    $2,490,265    $7,031,771    $6,236,949 
Natural gas   12,495    12,343    63,522    51,729 
Competitive businesses   481,100    395,650    1,355,961    1,165,153 
TOTAL   3,254,719    2,898,258    8,451,254    7,453,831 
                 
OPERATING EXPENSES                
Operating and Maintenance:                
  Fuel, fuel-related expenses, and                
   gas purchased for resale   987,558    607,307    2,489,347    1,525,652 
  Purchased power   607,777    748,552    1,646,555    1,788,736 
  Nuclear refueling outage expenses   43,045    41,432    127,584    120,393 
  Other operation and maintenance   590,992    490,483    1,693,657    1,552,858 
Decommissioning   36,933    35,056    108,787    108,579 
Taxes other than income taxes   133,527    98,717    327,995    284,349 
Depreciation and amortization   232,042    217,215    655,374    637,156 
Other regulatory charges (credits) - net   (21,563)   5,156    (124,509)   (44,814)
TOTAL   2,610,311    2,243,918    6,924,790    5,972,909 
                 
OPERATING INCOME   644,408    654,340    1,526,464    1,480,922 
                 
OTHER INCOME                
Allowance for equity funds used during construction   7,721    5,894    32,088    29,414 
Interest and dividend income   37,720    50,564    116,689    115,621 
Equity in earnings of unconsolidated equity affiliates   14,772    8,419    26,843    22,012 
Miscellaneous - net   30,964    (10,377)   16,793    4,599 
TOTAL   91,177    54,500    192,413    171,646 
                 
INTEREST AND OTHER CHARGES                
Interest on long-term debt   125,907    111,101    369,058    324,149 
Other interest - net   15,035    18,679    47,532    43,436 
Allowance for borrowed funds used during construction   (4,538)   (6,516)   (18,989)   (19,790)
TOTAL   136,404    123,264    397,601    347,795 
                 
INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES   599,181    585,576    1,321,276    1,304,773 
                 
Income taxes   202,437    222,080    444,170    466,172 
                 
INCOME FROM CONTINUING OPERATIONS   396,744    363,496    877,106    838,601 
                 
INCOME (LOSS) FROM DISCONTINUED OPERATIONS (net of income tax                
expense (benefit) of ($563), ($3,823), $5,423 and ($6,057) , respectively)   (1,050)   (7,108)   9,830    (11,286)
                 
                 
CONSOLIDATED NET INCOME   395,694    356,388    886,936    827,315 
                 
Preferred dividend requirements and other   6,811    6,436    22,622    19,217 
                 
EARNINGS APPLICABLE TO                
COMMON STOCK   $388,883    $349,952    $864,314    $808,098 
                 
Basic earnings (loss) per average common share:                
  Continuing operations   $1.87    $1.71    $4.11    $3.88 
  Discontinued operations     ($0.03)   $0.05    ($0.05)
  Basic earnings per average common share   $1.87    $1.68    $4.16    $3.83 
Diluted earnings (loss) per average common share:                
  Continuing operations   $1.83    $1.68    $4.03    $3.80 
  Discontinued operations     ($0.03)   $0.05    ($0.05)
  Diluted earnings per average common share   $1.83    $1.65    $4.08    $3.75 
Dividends declared per common share   $0.54    $0.54    $1.62    $1.62 
                 
Basic average number of common shares outstanding   208,382,863    207,906,762    208,034,946    211,033,629 
Diluted average number of common shares outstanding   212,404,770    212,335,619    211,782,858    215,540,185 
                 
See Notes to Consolidated Financial Statements.                

29

 

 

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2006 and 2005
(Unaudited)
    2006   2005
    (In Thousands)
   
OPERATING ACTIVITIES        
Consolidated net income   $886,936    $827,315 
Adjustments to reconcile consolidated net income to net cash flow        
 provided by operating activities:        
  Reserve for regulatory adjustments   43,960    (85,212)
  Other regulatory credits - net   (124,509)   (44,814)
  Depreciation, amortization, and decommissioning   765,627    747,397 
  Deferred income taxes and investment tax credits   (90,439)   204,297 
  Equity in earnings of unconsolidated equity affiliates - net of dividends   (24,669)   (16,712)
  Changes in working capital:        
    Receivables   210,311    (675,927)
    Fuel inventory   3,652    (10,407)
    Accounts payable   (390,804)   508,648 
    Taxes accrued   768,251    186,803 
    Interest accrued   3,190    15,231 
    Deferred fuel   436,663    (267,441)
    Other working capital accounts   111,491    (64,075)
  Provision for estimated losses and reserves   27,595    5,755 
  Changes in other regulatory assets   (193,323)   (316,327)
  Other   (176,575)   92,417 
Net cash flow provided by operating activities   2,257,357    1,106,948 
         
INVESTING ACTIVITIES        
Construction/capital expenditures   (1,233,505)   (877,165)
Allowance for equity funds used during construction   32,088    29,414 
Nuclear fuel purchases   (260,759)   (260,587)
Proceeds from sale/leaseback of nuclear fuel   135,079    174,140 
Proceeds from sale of assets and businesses   77,159   
Payment for purchase of plant   (88,199)   (162,075)
Decrease in other investments   56,501    19,698 
Purchases of other temporary investments     (1,591,025)
Liquidation of other temporary investments     1,778,975 
Proceeds from nuclear decommissioning trust fund sales   580,745    711,494 
Investment in nuclear decommissioning trust funds   (655,788)   (786,635)
Other regulatory investments   (38,506)   (240,232)
Net cash flow used in investing activities   (1,395,185)   (1,203,998)
         
See Notes to Consolidated Financial Statements.        
         

30

         
ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2006 and 2005
(Unaudited)
    2006   2005
    (In Thousands)
     
FINANCING ACTIVITIES        
Proceeds from the issuance of:        
  Long-term debt   1,377,701    2,538,976 
  Preferred stock   73,354    29,998 
  Common stock and treasury stock   32,072    114,552 
Retirement of long-term debt   (1,598,425)   (1,366,909)
Repurchase of common stock     (878,188)
Redemption of preferred stock   (183,881)   (33,719)
Changes in credit line borrowings - net   (40,000)   39,850 
Dividends paid:        
  Common stock   (337,104)   (341,437)
  Preferred stock   (22,861)   (19,087)
Net cash flow provided by (used in) financing activities   (699,144)   84,036 
         
Effect of exchange rates on cash and cash equivalents   (820)   (787)
         
Net increase (decrease) in cash and cash equivalents   162,208    (13,801)
         
Cash and cash equivalents at beginning of period   582,820    619,786 
         
Effect of the deconsolidation of Entergy New Orleans on cash and cash equivalents    -    (7,954)
         
Cash and cash equivalents at end of period   $745,028    $598,031 
         
         
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:        
  Cash paid (received) during the period for:        
    Interest - net of amount capitalized   $390,059    $332,056 
    Income taxes   ($197,560)   $118,989 
         
See Notes to Consolidated Financial Statements.        
         

 

31

 

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2006 and December 31, 2005
(Unaudited)
    2006   2005
    (In Thousands)
         
CURRENT ASSETS        
Cash and cash equivalents:        
  Cash   $136,421    $221,773 
  Temporary cash investments - at cost,        
   which approximates market   608,607    361,047 
     Total cash and cash equivalents   745,028    582,820 
Note receivable - Entergy New Orleans DIP loan   31,841    90,000 
Notes receivable   1,127    3,227 
Accounts receivable:        
  Customer   631,983    629,717 
  Allowance for doubtful accounts   (19,553)   (30,805)
  Other   438,359    459,152 
  Accrued unbilled revenues   292,612    477,570 
     Total receivables   1,343,401    1,535,634 
Deferred fuel costs   73,722    543,927 
Fuel inventory - at average cost   202,543    206,195 
Materials and supplies - at average cost   594,870    610,932 
Deferred nuclear refueling outage costs   104,511    157,764 
Prepayments and other   89,291    325,795 
TOTAL   3,186,334    4,056,294 
         
OTHER PROPERTY AND INVESTMENTS        
Investment in affiliates - at equity   323,007    296,784 
Decommissioning trust funds   2,748,771    2,606,765 
Non-utility property - at cost (less accumulated depreciation)   213,179    228,833 
Other   40,630    81,535 
TOTAL   3,325,587    3,213,917 
         
PROPERTY, PLANT AND EQUIPMENT        
Electric   30,429,958    29,161,027 
Property under capital lease   723,614    727,565 
Natural gas   89,685    86,794 
Construction work in progress   815,266    1,524,085 
Nuclear fuel under capital lease   248,506    271,615 
Nuclear fuel   462,338    436,646 
TOTAL PROPERTY, PLANT AND EQUIPMENT   32,769,367    32,207,732 
Less - accumulated depreciation and amortization   13,413,896    13,010,687 
PROPERTY, PLANT AND EQUIPMENT - NET   19,355,471    19,197,045 
         
DEFERRED DEBITS AND OTHER ASSETS        
Regulatory assets:        
  SFAS 109 regulatory asset - net   777,042    735,221 
  Other regulatory assets   2,376,634    2,133,724 
  Deferred fuel costs   168,122    120,489 
Long-term receivables   22,989    25,572 
Goodwill   377,172    377,172 
Other   968,303    991,835 
TOTAL   4,690,262    4,384,013 
          
TOTAL ASSETS   $30,557,654    $30,851,269 
         
See Notes to Consolidated Financial Statements.        
 
32
 
ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND SHAREHOLDERS' EQUITY
September 30, 2006 and December 31, 2005
(Unaudited)
    2006   2005
    (In Thousands)
         
CURRENT LIABILITIES        
Currently maturing long-term debt   $108,191    $103,517 
Notes payable   41    40,041 
Accounts payable   869,185    1,655,787 
Customer deposits   239,612    222,206 
Taxes accrued   254,205    188,159 
Accumulated deferred income taxes   36,805    143,409 
Nuclear refueling outage costs   4,791    15,548 
Interest accrued   158,045    154,855 
Obligations under capital leases   136,944    130,882 
Other   329,125    473,510 
TOTAL   2,136,944    3,127,914 
         
NON-CURRENT LIABILITIES        
Accumulated deferred income taxes and taxes accrued   5,958,146    5,279,228 
Accumulated deferred investment tax credits   363,050    376,550 
Obligations under capital leases   183,835    175,005 
Other regulatory liabilities   431,901    408,667 
Decommissioning and retirement cost liabilities   1,994,185    1,923,971 
Transition to competition   79,098    79,101 
Regulatory reserves   15,916    18,624 
Accumulated provisions   515,547    556,028 
Long-term debt   8,614,114    8,824,493 
Preferred stock with sinking fund   10,500    13,950 
Other   1,351,123    1,879,017 
TOTAL   19,517,415    19,534,634 
         
Commitments and Contingencies        
         
Preferred stock without sinking fund   345,035    445,974 
         
SHAREHOLDERS' EQUITY        
Common stock, $.01 par value, authorized 500,000,000        
 shares; issued 248,174,087 shares in 2006 and in 2005   2,482    2,482 
Paid-in capital   4,818,892    4,817,637 
Retained earnings   5,950,786    5,428,407 
Accumulated other comprehensive loss   (101,808)   (343,819)
Less - treasury stock, at cost (39,606,024 shares in 2006 and        
 40,644,602 shares in 2005)   2,112,092    2,161,960 
TOTAL   8,558,260    7,742,747 
         
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY   $30,557,654    $30,851,269 
         
See Notes to Consolidated Financial Statements.        

 

33

 

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF RETAINED EARNINGS, COMPREHENSIVE INCOME, AND PAID-IN CAPITAL
For the Three and Nine Months Ended September 30, 2006 and 2005
(Unaudited)
                     
        Three Months Ended
        2006   2005
        (In Thousands)
RETAINED EARNINGS                    
Retained Earnings - Beginning of period       $5,676,094        $5,212,985     
  Add: Earnings applicable to common stock       388,883    $388,883    349,952    $349,952 
  Deduct:                    
    Dividends declared on common stock       112,570        112,166     
    Capital stock and other expenses       1,621        553     
     Total       114,191        112,719     
Retained Earnings - End of period       $5,950,786        $5,450,218     
                     
ACCUMULATED OTHER COMPREHENSIVE LOSS                    
Balance at beginning of period                    
  Accumulated derivative instrument fair value changes       ($194,629)       ($208,067)    
  Other accumulated comprehensive income items       40,804        61,060     
     Total       (153,825)       (147,007)    
                     
Net derivative instrument fair value changes                    
 arising during the period (net of tax expense (benefit) of $17,470 and ($77,484))       27,295     27,295    (116,238)   (116,238)
                     
Foreign currency translation (net of tax expense of $143 and $493)       265    265    916    916 
                     
Minimum pension liability (net of tax expense of $386)       617    617     
                     
Net unrealized investment gains (net of tax expense (benefit) of $18,788 and ($651))       23,840    23,840    (3,548)   (3,548)
                     
Balance at end of period:                    
  Accumulated derivative instrument fair value changes       ($167,334)       ($324,305)    
  Other accumulated comprehensive income items       65,526        58,428     
     Total       ($101,808)       ($265,877)    
Comprehensive Income           $440,900        $231,082 
                     
PAID-IN CAPITAL                    
Paid-in Capital - Beginning of period       $4,817,628        $4,845,037     
 Add: Common stock issuances related to stock plans       1,264        (5,227)    
Paid-in Capital - End of period       $4,818,892        $4,839,810     
                     
                     
        Nine Months Ended
        2006   2005
        (In Thousands)
RETAINED EARNINGS                    
Retained Earnings - Beginning of period       $5,428,407        $4,984,302     
  Add: Earnings applicable to common stock       864,314    $864,314    808,098    $808,098 
  Deduct:                    
    Dividends declared on common stock       337,004        341,614     
    Capital stock and other expenses       4,931        568     
     Total       341,935        342,182     
Retained Earnings - End of period       $5,950,786        $5,450,218     
                     
ACCUMULATED OTHER COMPREHENSIVE LOSS                    
Balance at beginning of period                    
  Accumulated derivative instrument fair value changes       ($392,614)       ($141,411)    
  Other accumulated comprehensive income items       48,795        47,958     
     Total       (343,819)       (93,453)    
                     
Net derivative instrument fair value changes                    
 arising during the period (net of tax expense (benefit) of $149,013 and ($115,176))       225,280     225,280    (182,894)   (182,894)
                     
Foreign currency translation (net of tax expense of $442 and $424)       821    821    787    787 
                     
Minimum pension liability (net of tax expense (benefit) of $386 and ($1,344))       617    617    (2,054)   (2,054)
                     
Net unrealized investment gains (net of tax expense of $10,986 and $8,794)       15,293    15,293    11,737    11,737 
                     
Balance at end of period:                    
  Accumulated derivative instrument fair value changes       ($167,334)       ($324,305)    
  Other accumulated comprehensive income items       65,526        58,428     
     Total       ($101,808)       ($265,877)    
Comprehensive Income           $1,106,325        $635,674 
                     
PAID-IN CAPITAL                    
Paid-in Capital - Beginning of period       $4,817,637        $4,835,375     
  Add: Common stock issuances related to stock plans       1,255        4,435     
Paid-in Capital - End of period       $4,818,892        $4,839,810     
                     
                     
See Notes to Consolidated Financial Statements.                    
                     
                     

 

34

 

ENTERGY CORPORATION AND SUBSIDIARIES
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2006 and 2005
(Unaudited)
 
                 
    Three Months Ended   Increase/    
Description   2006   2005   (Decrease)   %
    (Dollars In Millions)    
U.S. Utility Electric Operating Revenues:                
  Residential   $1,115   $1,002   $113    11 
  Commercial   687   601   86    14 
  Industrial   704   642   62    10 
  Governmental   42   37     14 
     Total retail   2,548   2,282   266    12 
  Sales for resale   147   189   (42)   (22)
  Other   66   19   47    247 
     Total   $2,761   $2,490   $271    11 
                 
U.S. Utility Billed Electric Energy                
 Sales (GWh):                
  Residential   10,772   10,630   142   
  Commercial   7,484   7,301   183   
  Industrial   10,154   9,736   418   
  Governmental   436   424   12   
     Total retail   28,846   28,091   755   
  Sales for resale   2,894   3,184   (290)   (9)
     Total   31,740   31,275    465   
                 
                 
    Nine Months Ended   Increase/    
Description   2006   2005   (Decrease)   %
    (Dollars In Millions)    
U.S. Utility Electric Operating Revenues:                
  Residential   $2,509   $2,164   $345    16 
  Commercial   1,773   1,469   304    21 
  Industrial   1,990   1,742   248    14 
  Governmental   118   101   17    17 
     Total retail   6,390   5,476   914    17 
  Sales for resale   488   474   14   
  Other   154   287   (133)   (46)
     Total   $7,032   $6,237   $795    13 
                 
U.S. Utility Billed Electric Energy                
 Sales (GWh):                
  Residential   24,768   24,358   410   
  Commercial   19,078   18,507   571   
  Industrial   28,768   28,837   (69)  
  Governmental   1,196   1,184   12   
     Total retail   73,810   72,886   924   
  Sales for resale   8,471   8,811   (340)   (4)
     Total   82,281   81,697   584   
                 
                 

35

 

ENTERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)

NOTE 1. COMMITMENTS AND CONTINGENCIES

Entergy New Orleans Bankruptcy

See Note 9 to the consolidated financial statements for information on the Entergy New Orleans bankruptcy proceeding.

Nuclear Insurance

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

Non-Nuclear Property Insurance

See Note 8 to the consolidated financial statements in the Form 10-K for information on Entergy's non-nuclear property insurance program. Beginning in June 2006, the aggregation limit for all parties insured by Oil Insurance Limited (OIL) for any one occurrence was reduced to $500 million. Most of Entergy's non-nuclear excess property insurance coverage includes a $75 million drop-down feature in the event of an OIL aggregation loss to which an Entergy loss contributes.

Nuclear Decommissioning and Other Asset Retirement Costs

See Note 8 to the consolidated financial statements in the Form 10-K for information on nuclear decommissioning and other retirement costs. In the third quarter of 2006, Entergy's Non-Utility Nuclear business recorded a reduction of $27.0 million in its decommissioning cost liabilities in conjunction with a new decommissioning cost study as a result of revised decommissioning costs and changes in assumptions regarding the timing of when the decommissioning of a plant will begin. The revised estimate resulted in miscellaneous income of $27.0 million ($16.6 million net-of-tax), reflecting the excess of the reduction in the liability over the amount of undepreciated asset retirement cost.

Employment Litigation

Entergy Corporation and certain subsidiaries are defendants in numerous lawsuits filed by former employees asserting that they were wrongfully terminated and/or discriminated against on the basis of age, race, sex, or other protected characteristics. The defendant companies deny any liability to the plaintiffs.

NOTE 2. RATE AND REGULATORY MATTERS

Storm Costs Recovery Filings with Retail Regulators

On July 31, 2006, Entergy Louisiana and Entergy Gulf States filed a supplemental and amending storm cost recovery application with the LPSC, in which Entergy Louisiana and Entergy Gulf States requested that the LPSC (1) review Entergy Louisiana's and Entergy Gulf States' testimony and exhibits relating to the costs associated with Hurricanes Katrina and Rita, and declare that those verified, actual storm-related costs through May 31, 2006 are $466.8 million for Entergy Louisiana and $200.3 million for Entergy Gulf States in the Louisiana jurisdiction and that those costs were prudently incurred; (2) declare that the annual revenue requirements associated with the recovery of those costs, including carrying costs, based on a ten-year levelized rate are $54.4 million for Entergy Louisiana and $26.2 million for Entergy Gulf States; (3) authorize Entergy Louisiana and Entergy

 

36

 

 Gulf States to recover the costs through Storm Cost Recovery Riders (SCRRs) proposed by Entergy Louisiana and Entergy Gulf States; (4) declare that the storm costs incurred subsequent to May 31, 2006 are to be filed by Entergy Louisiana and Entergy Gulf States with the LPSC on an annual basis in connection with their annual formula rate plan (FRP) filings, and that the SCRRs be adjusted annually to reflect such costs and any insurance proceeds or CDBG funds actually received, with the adjusted amounts to be collected through the SCRRs to take effect contemporaneous with the effective date of rate changes under the FRP; (5) declare that the storm-related costs incurred by Entergy Louisiana and Entergy Gulf States meet the conditions set forth in the FRP for exclusion from the sharing provisions in those FRPs and authorize the permanent recovery of storm costs outside of the FRPs adopted by the LPSC for Entergy Louisiana and Entergy Gulf States; and (6) authorize the funding of a storm reserve through securitization sufficient to fund a storm cost reserve of $132 million for Entergy Louisiana and $81 million for Entergy Gulf States. Hearings are scheduled for March 2007. Entergy Gulf States and Entergy Louisiana also intend to pursue securitization options for the storm cost recovery as well, which is authorized by a law signed by the Governor of Louisiana in May 2006.

In July 2006, Entergy Gulf States filed an application with the PUCT with respect to the $393.2 million of Hurricane Rita reconstruction costs incurred in its Texas retail jurisdiction through March 31, 2006. The filing asks the PUCT to determine that $393.2 million is the amount of reasonable and necessary hurricane reconstruction costs eligible for securitization and recovery, approve the recovery of carrying costs, and approve the manner in which Entergy Gulf States allocates those costs among its Texas retail customer classes.  If approved, Entergy Gulf States' application will ultimately affect all its retail customers in Texas. Entergy Gulf States' filing does not request recovery of costs through a specific rider on customer bills or through any other means at this time. This is the first of two filings authorized by a law passed earlier this year in a special session of the Texas Legislature. A hearing before the PUCT on the filing was scheduled for November 1-3, 2006, but at the commencement of the hearing all of the parties in attendance announced that they had reached a unanimous agreement in principle to settle the issues in the proceeding. The parties are developing the documentation to formalize the settlement. The parties intend to submit the settlement documents to the PUCT prior to Thanksgiving 2006 so that the PUCT can approve them by early December 2006. A second filing will request securitization and recovery of the costs eligible for securitization through retail rates and tariffs. Entergy Gulf States expects to make the second filing following the conclusion of the reconstruction cost case.

In March 2006, the Governor of Mississippi signed a law that established a mechanism by which the MPSC could authorize and certify an electric utility financing order and the state could issue general obligation bonds to finance the costs of repairing damage caused by Hurricane Katrina to the systems of investor-owned electric utilities.  Because of the passage of this law and the possibility of Entergy Mississippi obtaining CDBG funds for Hurricane Katrina storm restoration costs, in March 2006, the MPSC issued an order approving a Joint Stipulation between Entergy Mississippi and the Mississippi Public Utilities Staff that provided for a review of Entergy Mississippi's total storm restoration costs in an Application for an Accounting Order proceeding.  The Stipulation stated that the procedural schedule of Entergy Mississippi's December 2005 filing seeking recovery of hurricane costs through an existing Entergy Mississippi storm damage rider should be suspended until the MPSC issues a final order in the Application for an Accounting Order proceeding. 

In June 2006, the MPSC issued an order certifying Entergy Mississippi's Hurricane Katrina restoration costs incurred through March 31, 2006 of $89 million, net of estimated insurance proceeds. Two days later, Entergy Mississippi filed a request with the Mississippi Development Authority for $89 million of CDBG funding for reimbursement of its Hurricane Katrina infrastructure restoration costs. Entergy Mississippi also filed a Petition for Financing Order with the MPSC for authorization of state general obligation bond financing of $169 million for Hurricane Katrina restoration costs and future storm costs. The $169 million amount included the $89 million of Hurricane Katrina restoration costs plus $80 million to build Entergy Mississippi's storm damage reserve for the future. Entergy Mississippi's filing stated that the amount actually financed through the state bonds would be net of any CDBG funds that Entergy Mississippi received.

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In October 2006, the Mississippi Development Authority approved for payment and Entergy Mississippi received $81 million in CDBG funding for Hurricane Katrina costs. The MPSC then issued a financing order authorizing the issuance of $48 million of state general obligation bonds, with $8 million for the remainder of Entergy Mississippi's certified Hurricane Katrina restoration costs and $40 million for the increase in Entergy Mississippi's storm damage reserve. $30 million of the storm reserve will be set aside in a restricted account. Entergy Mississippi expects to forward the financing order to the state bond commission, as per the March 2006 law, and expects to receive the proceeds from the state general obligation bond issuance in the first quarter of 2007.

Deferred Fuel Costs

See Note 2 to the consolidated financial statements in the Form 10-K for information regarding fuel proceedings involving the domestic utility companies.

Entergy Arkansas

In March 2006, Entergy Arkansas filed with the APSC its annual redetermination of the energy cost rate for application to the period April 2006 through March 2007. The filed energy cost rate of $0.02827 per kWh was proposed to replace the interim rate of $0.01900 per kWh that had been in place since October 2005. The interim energy cost rate is discussed in Note 2 to the financial statements in the Form 10-K, along with the investigation that the APSC commenced concerning Entergy Arkansas' interim energy cost rate. The increase in the energy cost rate is due to increases in the cost of purchased power primarily due to the natural gas cost increase and the effect that Hurricanes Katrina and Rita had on market conditions, increased demand for purchased power during the ANO 1 refueling and steam generator replacement outage in the fall of 2005, and coal plant generation curtailments during off-peak periods due to railroad delivery problems.

On March 31, 2006, the APSC suspended implementation of the $0.02827 per kWh energy cost rate, and ordered that the $0.01900 per kWh interim rate remain in effect pending the APSC proceedings on the energy cost recovery filings. The APSC also extended its investigation into Entergy Arkansas' interim energy cost rate to cover the costs included in Entergy Arkansas' March 2006 filing. The extended investigation did not identify new issues in addition to the four issues listed in the Form 10-K and covers the same time period. On April 7, 2006, the APSC issued a show cause order in the investigation proceeding that ordered Entergy Arkansas to file a cost of service study by June 8, 2006. The order also directed Entergy Arkansas to file testimony to support the cost of service study, to support the $0.02827 per kWh cost rate, and to address the general topic of elimination of the energy cost recovery rider.

In June 2006, Entergy Arkansas filed a motion with the APSC seeking again to implement the redetermined energy cost rate of $0.02827 per kWh. After a hearing, the APSC approved Entergy Arkansas' request and the redetermined rate was implemented in July 2006, subject to refund pending the outcome of the APSC energy cost recovery investigation. Because of the delay in implementing the redetermined energy cost rate, Entergy Arkansas estimated in its motion that $46 million of energy costs would remain under-recovered at December 31, 2006.

On June 7, 2006, Entergy Arkansas filed a cost of service study and testimony supporting the redetermined energy cost rate and testimony addressing the prospective elimination of the energy cost recovery rider as ordered by the APSC. A hearing was held in the APSC energy cost recovery investigation on October 12, 2006 and post-hearing briefs were filed by Entergy Arkansas, the APSC General Staff, the Arkansas Attorney General, and the Arkansas Electric Energy Consumers. No party recommended termination of the energy cost recovery rider in the fuel cost investigation proceeding. The timing of a decision in this proceeding is uncertain.

Entergy Gulf States

In March 2006, Entergy Gulf States filed with the PUCT an application to implement an interim fuel surcharge in connection with the under-recovery of $97 million including interest on eligible fuel costs for the period August 2005 through January 2006. This surcharge is in addition to an interim surcharge that went into effect in January 2006. Entergy Gulf States entered into a unanimous settlement that reduced the requested surcharge for

 

38

 

 actual over-collections from the months of February and March 2006, resulting in a surcharge of $78.8 million to be implemented over a twelve-month period beginning in June 2006. The PUCT approved the surcharge in June 2006. Entergy Gulf States has since entered into a joint agreement with several parties, which was approved by the PUCT, to remove the first interim fuel surcharge (the January 2006 surcharge) effective with the first billing cycle in November 2006. That surcharge was to be in effect until the end of 2006. Additionally, Entergy Gulf States requested that the PUCT remove the second interim surcharge (the June 2006 surcharge) as of November 2006 as well, which the PUCT has approved. Both of these requests are the result of over-recoveries in recent months. Amounts collected through the interim fuel surcharges are subject to final reconciliation in a future fuel reconciliation proceeding.

In May 2006, Entergy Gulf States filed with the PUCT a fuel and purchased power reconciliation case covering the period September 2003 through December 2005 for costs recoverable through the Texas fixed fuel factor rate and the incremental purchased capacity recovery rider. Entergy Gulf States is reconciling $1.6 billion of fuel and purchased power costs on a Texas retail basis. Hearings are scheduled for February 2007 and a PUCT decision is expected in July 2007.

Entergy Gulf States and Entergy Louisiana

In November 2005, the LPSC authorized its staff to initiate an expedited proceeding to audit the fuel and power procurement activities of Entergy Louisiana and Entergy Gulf States for the period January 1, 2005 through October 31, 2005. In April 2006, the LPSC accepted the LPSC Staff's audit report finding that the prices paid for natural gas and purchased power were reasonable and that given the market conditions surrounding Hurricanes Katrina and Rita, Entergy Louisiana and Entergy Gulf States acted reasonably and prudently in response to an extremely difficult environment.

Retail Rate Proceedings

See Note 2 to the consolidated financial statements in the Form 10-K for information regarding retail rate proceedings involving the domestic utility companies. The following are updates to the Form 10-K.

Filings with the APSC

In August 2006, Entergy Arkansas filed with the APSC a request for a change in base rates. Entergy Arkansas requested a general base rate increase of $150 million (using an ROE of 11.25%), as well as recovery of FERC-allocated costs pursuant to the FERC decision on the System Agreement. Entergy Arkansas also requested a capacity management rider to recover incremental capacity costs. A procedural schedule has been established with hearings expected to begin in April 2007.

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - System Agreement Litigation " in the Form 10-K and herein for a discussion of Entergy's compliance filing in that proceeding. If the FERC approves the compliance tariff as filed, then payments under that tariff will be classified as energy costs, which would then be included in setting the retail energy cost rate as part of the normal working of the energy cost recovery rider.  As noted above, the APSC has given notice that it is considering the prospective elimination of the energy cost recovery rider.  Therefore, Entergy Arkansas proposed in the August 2006 base rate case an alternative to the energy cost recovery rider for recovery of the costs allocated to it as a result of the System Agreement litigation should the energy cost recovery rider be lawfully terminated by the APSC.  A separate exact recovery rider, similar to the energy cost recovery rider, would ensure that Entergy Arkansas customers pay only the amount allocated by the FERC.

Filings with the PUCT and Texas Cities

As discussed in the Form 10-K, in August 2005, Entergy Gulf States filed with the PUCT an application for recovery of its transition to competition costs. Entergy Gulf States requested recovery of $189 million in transition to competition costs through implementation of a 15-year rider to be effective no later than March 1, 2006. The $189 million represents transition to competition costs Entergy Gulf States incurred from June 1, 1999

 

39

 

 through June 17, 2005 in preparing for competition in its Texas service area, including attendant AFUDC, and all carrying costs projected to be incurred on the transition to competition costs through February 28, 2006. The $189 million is before any gross-up for taxes or carrying costs over the 15-year recovery period. Entergy Gulf States reached a unanimous settlement agreement on all issues with the active parties in the transition to competition cost recovery case. The agreement allows Entergy Gulf States to recover $14.5 million per year in transition to competition costs over a 15-year period. Entergy Gulf States implemented interim rates based on this revenue level on March 1, 2006. The PUCT approved the settlement agreement in June 2006.

Filings with the LPSC

Retail Rates - Electric

(Entergy Gulf States)

In March 2006, the LPSC approved an uncontested stipulated settlement in Entergy Gulf States' formula rate plan filing for the 2004 test year. The settlement includes a revenue requirement increase of $36.8 million and calls for Entergy Gulf States to apply a refund liability of $744 thousand to capacity deferrals. The refund liability pertained to the periods 2004-2005 as well as the interim period in which a $37.2 million revenue increase was in place.

In May 2006, Entergy Gulf States made its formula rate plan filing with the LPSC for the 2005 test year. Entergy Gulf States modified the filing in August 2006 to reflect an 11.1% return on equity which is within the allowed bandwidth. The modified filing includes a formula rate plan increase of $17.2 million which provides for interim recovery of storm costs from Hurricanes Katrina and Rita and recovery of LPSC-approved incremental deferred and ongoing capacity costs. The increase was implemented, subject to refund, with the first billing cycle of September 2006.

(Entergy Louisiana)

In May 2006, Entergy Louisiana made its formula rate plan filing with the LPSC for the 2005 test year. Entergy Louisiana modified the filing in August 2006 to reflect a 9.45% return on equity which is within the allowed bandwidth. The modified filing includes an increase of $24 million for interim recovery of storm costs from Hurricanes Katrina and Rita and a $120 million rate increase to recover LPSC-approved incremental deferred and ongoing capacity costs. The filing requested recovery of approximately $50 million for the amortization of capacity deferrals over a three-year period, including carrying charges, and approximately $70 million for ongoing capacity costs. The increase was implemented, subject to refund, with the first billing cycle of September 2006. Comments were provided by the LPSC Staff, which Entergy Louisiana is currently reviewing. Entergy Louisiana subsequently updated its formula rate plan rider to reflect adjustments proposed by the LPSC Staff with which it agrees. The adjusted return on equity of 9.56% remains within the allowed bandwidth. Ongoing and deferred incremental capacity costs were reduced to $119 million. The updated formula rate plan rider was implemented, subject to refund, with the first billing cycle of October 2006.

Retail Rates - Gas (Entergy Gulf States)

In January 2006, Entergy Gulf States filed with the LPSC its gas rate stabilization plan. The filing showed a revenue deficiency of $4.1 million based on an ROE mid-point of 10.5%. On May 1, 2006, Entergy Gulf States implemented a $3.5 million rate increase pursuant to an uncontested agreement with the LPSC Staff.

Filings with the MPSC

In March 2006, Entergy Mississippi made its annual scheduled formula rate plan filing with the MPSC.  The filing was amended by an April 2006 filing.  The amended filing showed that an increase of $3.1 million in electric revenues is warranted.  The MPSC has approved a settlement providing for a $1.8 million rate increase, which was implemented in August 2006.

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Filings with the City Council

In June 2006, Entergy New Orleans made its annual formula rate plan filings with the City Council.  The filings presented various alternatives to reflect the effect of Entergy New Orleans' lost customers and decreased revenue. Entergy New Orleans' recommended alternative adjusts for lost customers and assumes that the City Council's June 2006 decision to allow recovery of all Grand Gulf costs through the fuel adjustment clause stays in place during the rate-effective period (a significant portion of Grand Gulf costs was previously recovered through base rates).

At the same time as it made its formula rate plan filings, Entergy New Orleans also filed with the City Council a request to implement two storm-related riders. With the first rider, Entergy New Orleans sought to recover the electric and gas restoration costs that it had actually spent through March 31, 2006. Entergy New Orleans also proposed semiannual filings to update the rider for additional restoration spending and also to consider the receipt of CDBG funds or insurance proceeds that it may receive. With the second rider, Entergy New Orleans sought to establish a storm reserve to provide for the risk of another storm.

In October 2006 the City Council approved a settlement agreement that resolves Entergy New Orleans' rate and storm-related rider filings by providing for phased-in rate increases, while taking into account with respect to storm restoration costs the anticipated receipt of CDBG funding as recommended by the Louisiana Recovery Authority. The settlement provides for a 0% increase in electric base rates through December 2007, with a $3.9 million increase implemented in January 2008. Recovery of all Grand Gulf costs through the fuel adjustment clause will continue. Gas base rates will increase by $4.75 million in November 2006, an additional $1.5 million in March 2007, and an additional $4.75 million in November 2007. The settlement calls for Entergy New Orleans to file a base rate case by July 31, 2008. Any storm costs in excess of CDBG funding and insurance proceeds will be addressed in that base rate case. A storm cost recovery rider is authorized but initially set at $0 because of the anticipated receipt of CDBG funding. The settlement also authorizes a $75 million storm reserve for damage from future storms, which will be created over a ten-year period through a storm reserve rider beginning in March 2007. These storm reserve funds will be held in a restricted escrow account.

Customer-Initiated Proceeding at the FERC

As discussed in Part I, Item 1 of the Form 10-K, in September 2004, East Texas Electric Cooperative (ETEC) filed a complaint at the FERC against Entergy Arkansas relating to a contract dispute over the pricing of substitute energy at the co-owned Independence coal unit.  In October 2004, Arkansas Electric Cooperative (AECC) filed a similar complaint at the FERC against Entergy Arkansas, addressing the same issue with respect to Independence and another co-owned coal unit, White Bluff. FERC consolidated these cases, ordered a hearing in the consolidated proceeding, and established refund effective dates.  The main issue in the consolidated case relates to the consequences under the governing contracts when the dispatch of the coal units is constrained due to system operating conditions.  In August 2005, Entergy Arkansas and ETEC filed a settlement at the FERC that resolved all issues in dispute between ETEC and Entergy Arkansas. As part of the settlement, ETEC dismissed its complaint. A hearing was held on the AECC complaint and an ALJ Initial Decision was issued in January 2006 in which the ALJ found AECC's claims to be without merit. On October 25, 2006, the FERC issued an order on the ALJ's Initial Decision. In the order, the FERC reversed the ALJ's findings. Specifically, the FERC found that the governing contracts do not recognize the effects of dispatch constraints on the co-owned units. The FERC explained that for over twenty-three years the course of conduct of the parties was such that AECC received its full entitlement to the two coal units, regardless of any reduced output caused by system operating constraints. Based on the order, Entergy Arkansas is required to refund to AECC all excess amounts billed to AECC as a result of the system operating constraints. Entergy Arkansas estimates currently that this will result in a refund to AECC of approximately $26 million, although Entergy Arkansas is still refining the estimate. Requests for rehearing of the FERC's decision are due on November 24, 2006.

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NOTE 3. COMMON EQUITY

Common Stock

Earnings per Share

The following tables present Entergy's basic and diluted earnings per share (EPS) calculations included on the consolidated income statement:

 

 

For the Three Months Ended September 30,

 

 

2006

 

2005

 

 

(In Millions, Except Per Share Data)

 

 

 

 

$/share

 

 

 

$/share

Earnings applicable to common stock

 

$388.9

 

 

 

$350.0

 

 

 

 

 

 

 

 

 

 

 

Average number of common shares
outstanding - basic

 


208.4

 


$1.87 

 


207.9

 


$1.68 

Average dilutive effect of:

 

 

 

 

 

 

 

 

 

Stock Options

 

3.8

 

(0.034)

 

4.2

 

(0.033)

 

Deferred Units

 

0.2

 

(0.002)

 

0.2

 

(0.002)

Average number of common shares
outstanding - diluted

 


212.4

 


$1.83 

 


212.3

 


$1.65 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

For the Nine Months Ended September 30,

 

 

2006

 

2005

 

 

(In Millions, Except Per Share Data)

 

 

 

 

$/share

 

 

 

$/share

Earnings applicable to common stock

 

$864.3

 

 

 

$808.1

 

 

 

 

 

 

 

 

 

 

 

Average number of common shares
outstanding - basic

 


208.0

 


$4.16 

 


211.0

 


$3.83 

Average dilutive effect of:

 

 

 

 

 

 

 

 

 

Stock Options

 

3.6

 

(0.070)

 

4.3

 

(0.076)

 

Deferred Units

 

0.2

 

(0.004)

 

0.2

 

(0.005)

Average number of common shares
outstanding - diluted

 


211.8

 


$4.08 

 


215.5

 


$3.75 

 

 

 

 

 

 

 

 

 

Entergy's stock option and other equity compensation plans are discussed in Note 7 to the consolidated financial statements in the Form 10-K.

Treasury Stock

During the nine months ended September 30, 2006, Entergy Corporation issued 1,038,578 shares of its previously repurchased common stock to satisfy stock option exercises and other stock-based awards.

Retained Earnings

On October 27, 2006, Entergy Corporation's Board of Directors declared a common stock dividend of $0.54 per share, payable on December 1, 2006 to holders of record as of November 10, 2006.

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Accumulated Other Comprehensive Income

Cash flow hedges with net unrealized losses of approximately $130 million net-of-tax at September 30, 2006 are scheduled to mature during the next twelve months.

NOTE 4. LINES OF CREDIT, RELATED SHORT-TERM BORROWINGS, AND LONG-TERM DEBT

Entergy Corporation has in place two separate revolving credit facilities, a five-year credit facility and a three-year credit facility. The five-year credit facility, which expires in May 2010, has a borrowing capacity of $2 billion, of which $495 million was outstanding as of September 30, 2006. The three-year facility, which expires in December 2008, has a borrowing capacity of $1.5 billion, none of which was outstanding as of September 30, 2006. Entergy can issue letters of credit against the total borrowing capacity of both credit facilities, and letters of credit totaling $94.1 million had been issued against the five-year facility at September 30, 2006. The total unused capacity for these facilities as of September 30, 2006 was approximately $2.9 billion. The commitment fee for this facility is currently 0.13% per annum of the unused amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior debt ratings of the domestic utility companies.

Entergy Arkansas, Entergy Gulf States, and Entergy Mississippi, each has credit facilities available as of September 30, 2006 as follows:


Company

 


Expiration Date

 

Amount of
Facility

 

Amount Drawn as of
September 30, 2006

 

 

 

 

 

 

 

Entergy Arkansas

 

April 2007

 

$85 million

 

-

Entergy Gulf States

 

February 2011

 

$50 million (a)

 

-

Entergy Mississippi

 

May 2007

 

$30 million (b)

 

-

Entergy Mississippi

 

May 2007

 

$20 million (b)

 

-

(a)

The credit facility allows Entergy Gulf States to issue letters of credit against the borrowing capacity of the facility. As of September 30, 2006, $1.4 million in letters of credit had been issued.

(b)

Borrowings under the Entergy Mississippi facilities may be secured by a security interest in its accounts receivable.

In May 2006, Entergy Mississippi increased its $25 million credit facility to $30 million and renewed it through May 2007. Entergy Mississippi also entered into a new $20 million credit facility through May 2007.

The credit facilities have variable interest rates and the average commitment fee is 0.13%. The $85 million Entergy Arkansas credit facility requires that it maintain total shareholders' equity of at least 25% of its total assets.

The FERC has issued an order ("FERC Short-Term Order") approving the short-term borrowing limits of the domestic utility companies (except Entergy New Orleans) and System Energy through March 31, 2008. Entergy New Orleans may rely on existing SEC PUHCA 1935 orders for its financing authority, subject to bankruptcy court approval. In addition to borrowings from commercial banks, the FERC Short-Term Order authorized the domestic utility companies (except Entergy New Orleans, which is authorized by an SEC PUHCA 1935 order) and System Energy to continue as participants in the Entergy System money pool. The money pool is an inter-company borrowing arrangement designed to reduce Entergy's subsidiaries' dependence on external short-term borrowings. Borrowings from the money pool and external short-term borrowings combined may not exceed the authorized limits. As of September 30, 2006, Entergy's subsidiaries' aggregate authorized limit was $2.0 billion and the aggregate outstanding borrowing from the money pool was $346.9 million.

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Long-term Debt

The following long-term debt has been issued by Entergy in 2006:

 

Issue Date

 

Amount

 

 

 

(In Thousands)

U.S. Utility

 

 

 

Mortgage Bonds:

 

 

 

5.92% Series due February 2016 - Entergy Mississippi

January 2006

 

$100,000

Other Long-term Debt:

 

 

 

4.60% Series due October 2017, Jefferson County - Arkansas
 (Entergy Arkansas) (secured by a series of collateral first
 mortgage bonds)



June 2006



$54,700

The following long-term debt was retired by Entergy in 2006:

 

Retirement Date

 

Amount

 

 

 

(In Thousands)

U.S. Utility

 

 

 

Other Long-term Debt:

 

 

 

5.95% Series due December 2023, St. Charles Parish -
 Louisiana (Entergy Louisiana)


June 2006  


$25,000

Grand Gulf Lease Obligation payment (System Energy)

N/A

$22,989

5.6% Series due October 2017, Jefferson County - Arkansas
 (Entergy Arkansas)


July 2006


$45,500

6.3% Series due June 2018, Jefferson County - Arkansas
 (Entergy Arkansas)


July 2006


$9,200

Entergy Mississippi used the proceeds from the January 2006 issuance to purchase the Attala power plant from Central Mississippi Generating Company, LLC and to repay short-term indebtedness.

Entergy Arkansas used the proceeds from the June 2006 issuance to redeem, prior to maturity, the $45.5 million of 5.6% Series of Jefferson County bonds and $9.2 million of 6.3% Series of Jefferson County bonds in July 2006. The issuance is shown as a non-cash transaction on the cash flow statement since the proceeds were placed in a trust and never held as cash by Entergy Arkansas.

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NOTE 5. PREFERRED STOCK

In March 2006, Entergy Arkansas issued 3,000,000 shares of $25 par value 6.45% Series Preferred Stock, all of which were outstanding as of September 30, 2006. The dividends are cumulative and payable quarterly beginning July 1, 2006. The preferred stock is redeemable on or after April 1, 2011, at Entergy Arkansas' option, at the call price of $25 per share. In April 2006, Entergy Arkansas used the proceeds from this issuance to redeem the following preferred stock:

Series of Entergy Arkansas Preferred Stock

 

Redemption Price Per Share

     

7.32% Preferred Stock, Cumulative, $100.00 par value

 

$103.17

7.80% Preferred Stock, Cumulative, $100.00 par value

 

$103.25

7.40% Preferred Stock, Cumulative, $100.00 par value

 

$102.80

7.88% Preferred Stock, Cumulative, $100.00 par value

 

$103.00

$1.96 Preferred Stock, Cumulative, $0.01 par value

 

$ 25.00

In June 2006, Entergy Louisiana Holdings redeemed all of its preferred stock and amended its charter to eliminate authority to issue any future series of preferred stock. The redemption was made at the following respective redemption prices as provided in the Entergy Louisiana Holdings amended and restated articles of incorporation:

Series of Entergy Louisiana Holdings Preferred Stock

 

Redemption Price Per Share

4.96% Preferred Stock, Cumulative, $100.00 par value

 

$104.25

4.16% Preferred Stock, Cumulative, $100.00 par value

 

$104.21

4.44% Preferred Stock, Cumulative, $100.00 par value

 

$104.06

5.16% Preferred Stock, Cumulative, $100.00 par value

 

$104.18

5.40% Preferred Stock, Cumulative, $100.00 par value

 

$103.00

6.44% Preferred Stock, Cumulative, $100.00 par value

 

$102.92

7.84% Preferred Stock, Cumulative, $100.00 par value

 

$103.78

7.36% Preferred Stock, Cumulative, $100.00 par value

 

$103.36

8% Preferred Stock, Cumulative, $25.00 par value

 

$ 25.00

NOTE 6. STOCK-BASED COMPENSATION PLANS

Entergy grants stock options, which are described more fully in Note 7 to the consolidated financial statements in the Form 10-K. Entergy adopted SFAS 123R, "Share-Based Payment" on January 1, 2006. The effect of adoption of the standard did not materially affect Entergy's financial position, results of operations, or cash flows because Entergy adopted the fair value based method of accounting for stock options prescribed by SFAS 123, "Accounting for Stock-Based Compensation" on January 1, 2003. Prior to 2003, Entergy applied the recognition and measurement principles of APB Opinion 25, "Accounting for Stock Issued to Employees," and related Interpretations in accounting for those plans. Awards under Entergy's plans generally vest over three years. Stock-based compensation expense included in earnings applicable to common stock, net of related tax effects, for the third quarter 2006 and nine months ended September 30, 2006 is $2.0 million and $5.7 million, respectively. Stock-based compensation expense included in earnings applicable to common stock, net of related tax effects, for the third quarter 2005 and nine months ended September 30, 2005 is $2.0 million and $5.8 million, respectively.

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NOTE 7. RETIREMENT AND OTHER POSTRETIREMENT BENEFITS

Components of Net Pension Cost

Entergy's qualified pension cost, including amounts capitalized, for the third quarters of 2006 and 2005, included the following components:

 

 

2006

 

2005

 

 

(In Thousands)

 

 

 

 

 

Service cost - benefits earned during the period

 

$23,176 

 

$20,250 

Interest cost on projected benefit obligation

 

41,814 

 

40,254 

Expected return on assets

 

(44,482)

 

(40,989)

Amortization of transition asset

 

 

(165)

Amortization of prior service cost

 

1,365 

 

1,125 

Amortization of loss

 

10,931 

 

10,497 

Net pension costs

 

$32,804 

 

$30,972 

Entergy's qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2006 and 2005, included the following components:

 

 

2006

 

2005

 

 

(In Thousands)

 

 

 

 

 

Service cost - benefits earned during the period

 

$69,529 

 

$62,271 

Interest cost on projected benefit obligation

 

125,443 

 

115,222 

Expected return on assets

 

(133,447)

 

(118,552)

Amortization of transition asset

 

 

(497)

Amortization of prior service cost

 

4,096 

 

3,736 

Amortization of loss

 

32,790 

 

25,109 

Net pension costs

 

$98,411 

 

$87,289 

Entergy recognized $5.2 million and $4.1 million in pension cost for its non-qualified pension plans in the third quarters of 2006 and 2005, respectively. Entergy recognized $13.1 million and $12.2 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2006 and 2005, respectively.

Components of Net Other Postretirement Benefit Cost

Entergy's other postretirement benefit cost, including amounts capitalized, for the third quarters of 2006 and 2005, included the following components:

 

 

2006

 

2005

 

 

(In Thousands)

 

 

 

 

 

Service cost - benefits earned during the period

 

$10,370 

 

$9,447 

Interest cost on APBO

 

14,316 

 

12,441 

Expected return on assets

 

(4,756)

 

(4,338)

Amortization of transition obligation

 

542 

 

345 

Amortization of prior service cost

 

(3,688)

 

(4,881)

Amortization of loss

 

5,698 

 

5,877 

Net other postretirement benefit cost

 

$22,482 

 

$18,891 

46

Entergy's other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2006 and 2005, included the following components:

 

 

2006

 

2005

 

 

(In Thousands)

 

 

 

 

 

Service cost - benefits earned during the period

 

$31,110 

 

$27,863 

Interest cost on APBO

 

42,947 

 

39,443 

Expected return on assets

 

(14,268)

 

(13,065)

Amortization of transition obligation

 

1,627 

 

3,025 

Amortization of prior service cost

 

(11,063)

 

(8,859)

Amortization of loss

 

17,092 

 

16,421 

Net other postretirement benefit cost

 

$67,445 

 

$64,828 

Employer Contributions

Entergy previously disclosed in the Form 10-K that it expected to contribute $349 million to its qualified pension plans in 2006 (including $107 million delayed from 2005 as a result of the Katrina Emergency Tax Relief Act). Due to the Pension Protection Act, described below, Entergy has revised its 2006 contributions to $318 million. As of the end of October 2006, Entergy has contributed the $318 million to its pension plans.

The Pension Protection Act of 2006 was signed by the President on August 17, 2006. The intent of the legislation is to require companies to fund 100% of their pension liability; and then for companies to fund, on a going-forward basis, an amount generally estimated to be the amount that the pension liability increases each year due to an additional year of service by the employees eligible for pension benefits. The legislation requires that funding shortfalls be eliminated by companies over a seven-year period, beginning in 2008.

The Pension Protection Act also extended the provisions of the Pension Funding Equity Act that would have expired in 2006 had the Pension Protection Act not been enacted, which increased the allowed discount rate used to calculate the pension funding liability. The latter provision reduced Entergy's 2006 expected pension contributions by approximately $31 million.

Entergy is in the process of evaluating the effects of the new legislation, but expects that the implementation of the Pension Protection Act will not result in annual pension contributions going-forward that are materially higher than the levels required in 2005 and 2006.

Medicare Prescription Drug, Improvement and Modernization Act of 2003 (Medicare Act)

Based on actuarial analysis, the estimated effect of future Medicare subsidies reduced the December 31, 2005 Accumulated Postretirement Benefit Obligation by $176 million, and reduced the third quarter 2006 and 2005 other postretirement benefit cost by $6.9 million and $5.7 million, respectively. It reduced the nine months ended September 30, 2006 and 2005 other postretirement benefit cost by $20.8 million and $18.6 million, respectively. In the third quarter 2006, Entergy received $1.8 million in Medicare subsidies for prescription drug claims through June 2006. Refer to Note 10 to the consolidated financial statements in the Form 10-K for further discussion.

47

NOTE 8. BUSINESS SEGMENT INFORMATION

Entergy's reportable segments as of September 30, 2006 are Utility and Non-Utility Nuclear. "All Other" includes the parent company, Entergy Corporation, and other business activity, including the Energy Commodity Services segment, the Competitive Retail Services business, and earnings on the proceeds of sales of previously-owned businesses. As a result of the Entergy New Orleans bankruptcy filing, Entergy has discontinued the consolidation of Entergy New Orleans retroactive to January 1, 2005, and is reporting Entergy New Orleans results under the equity method of accounting in the Utility segment.

Entergy's segment financial information for the third quarters of 2006 and 2005 is as follows:

 



Utility

 


Non-Utility
Nuclear*

 



All Other*

 



Eliminations

 



Consolidated

(In Thousands)

2006

 

 

 

 

 

 

 

 

 

Operating revenues

$2,774,447

 

$409,431

 

$77,571 

 

($6,730)

 

$3,254,719 

Equity in earnings of
 unconsolidated equity affiliates


7,336

 


-

 

7,436 

 


 


14,772 

Income taxes

141,009

 

57,494

 

3,934 

 

 

202,437 

Income (loss) from continuing
 operations

295,989

106,898

(6,269)

126 

396,744 

Loss from discontinued
 operations (net of income taxes)


-


-


(1,050)



(1,050)

Net income (loss)

295,989

 

106,898

 

(7,319)

 

126 

 

395,694 

 

 

 

 

 

 

 

2005

 

 

 

 

 

 

 

 

 

Operating revenues

$2,503,000

 

$360,777

 

$56,601 

 

($22,120)

 

$2,898,258 

Equity in earnings of
 unconsolidated equity affiliates


6,417

 


-

 


2,002 

 


 


8,419 

Income taxes (benefit)

185,594

 

41,018

 

(4,532)

 

 

222,080 

Income (loss) from continuing
 operations

304,459

69,253

(10,293)

77 

363,496 

Loss from discontinued operations
 (net of income tax benefit)


-


-


(7,108)



(7,108)

Net income (loss)

304,459

 

69,253

 

(17,401)

 

77 

 

356,388 

48

Entergy's segment financial information for the nine months ended September 30, 2006 and 2005 is as follows:

 



Utility

 


Non-Utility
Nuclear*

 



All Other*

 



Eliminations

 



Consolidated

(In Thousands)

2006

 

 

 

 

 

 

 

 

 

Operating revenues

$7,097,362 

 

$1,159,803 

 

$227,043 

 

($32,954)

 

$8,451,254 

Equity in earnings of
 unconsolidated equity affiliates


23,661 

 


 

3,182 

 


 


26,843 

Income taxes (benefit)

311,760 

 

151,742 

 

(19,332)

 

 

444,170 

Income (loss) from continuing
 operations

629,464 

251,806 

(4,174)

10 

877,106 

Income from discontinued
 operations (net of income taxes)




9,830 



9,830 

Net income

629,464 

 

251,806 

 

5,656 

 

10 

 

886,936 

Total assets

24,751,827 

 

5,230,065 

 

2,851,702 

 

(2,275,940)

 

30,557,654 

 

 

 

 

 

 

 

 

 

 

2005

 

 

 

 

 

 

 

 

 

Operating revenues

$6,289,865 

 

$1,052,058 

 

$170,020 

 

($58,112)

 

$7,453,831 

Equity in earnings of
 unconsolidated equity affiliates


20,045 

 


 

1,967 

 


 


22,012 

Income taxes (benefit)

363,212 

 

127,164 

 

(24,204)

 

 

466,172 

Income from continuing operations

617,745 

205,495 

15,331 

30 

838,601 

Loss from discontinued operations
 (net of income tax benefit)




(11,286)



(11,286)

Net income

617,745 

 

205,495 

 

4,045 

 

30 

 

827,315 

Total assets

24,243,609 

 

4,893,308 

 

3,629,739 

 

(2,799,914)

 

29,966,742 

Businesses marked with * are sometimes referred to as the "competitive businesses," with the exception of the parent company, Entergy Corporation. Eliminations are primarily intersegment activity.

In April 2006, Entergy sold the retail electric portion of the Competitive Retail Services business operating in the ERCOT region of Texas, and now reports this portion of the business as a discontinued operation. Entergy realized a $26.3 million gain ($17.1 million net-of-tax) on the sale.

NOTE 9. ENTERGY NEW ORLEANS BANKRUPTCY PROCEEDING

See Note 16 to the consolidated financial statements in the Form 10-K for a discussion of the Entergy New Orleans bankruptcy proceeding, and a discussion of Entergy's decision to deconsolidate its investment in Entergy New Orleans and report it under the equity method of accounting. Entergy's income statement for the three and nine months ended September 30, 2006 includes $48 million and $177 million, respectively, in operating revenues and $19 million and $30 million, respectively, in purchased power expenses from transactions between Entergy New Orleans and Entergy's subsidiaries. Entergy's income statement for the three and nine months ended September 30, 2005 includes $53 million and $139 million, respectively, in operating revenues and $26 million and $107 million, respectively, in purchased power from transactions between Entergy New Orleans and Entergy's subsidiaries. Entergy's balance sheet as of September 30, 2006 includes $109 million of accounts receivable that are payable to Entergy or its subsidiaries by Entergy New Orleans, including $66.8 million of pre-petition accounts.

As discussed in the Form 10-K, because Entergy owns all of the common stock of Entergy New Orleans, Entergy's deconsolidation of Entergy New Orleans does not affect the amount of net income Entergy records resulting from Entergy New Orleans' operations.

49

NOTE 10. ACCOUNTING POLICY UPDATE

Revenue and Fuel Costs

Entergy recognizes revenue from electric power and gas sales when it delivers power or gas to its customers. To the extent that deliveries have occurred but a bill has not been issued, the domestic utility companies accrue an estimate of the revenues for energy delivered since the latest billings. Entergy calculates the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and prices in effect in the domestic utility companies' various jurisdictions. Changes are made to the inputs in the estimate as needed to reflect changes in billing practices.  Modifications made to the billing system in the third quarter 2006 provide better information related to the amount of generation that remains unbilled at the end of each month.  Accordingly, the domestic utility companies refined the calculation of unbilled revenue to reflect this additional information.  This refinement added $25.7 million to unbilled revenue in the third quarter 2006.  Each month the estimated unbilled revenue amounts are recorded as revenue and unbilled accounts receivable, and the prior month's estimate is reversed. Therefore, changes in price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the next, and may result in variability in reported revenues from one period to the next as prior estimates are so recorded and reversed.

Prior to 2006, Entergy Louisiana and the Louisiana portion of Entergy Gulf States included a component of fuel cost recovery in their unbilled revenue calculations. Effective January 1, 2006, this fuel component of unbilled accounts receivable was reclassified to deferred fuel and is no longer included in the unbilled revenue calculations for Entergy Louisiana and the Louisiana portion of Entergy Gulf States, which is in accordance with regulatory treatment.

Recently Issued Accounting Pronouncements

FASB Interpretation No. 48, "Accounting for Uncertainty in Income Taxes" (FIN 48) was issued in July 2006 and is effective for Entergy in the first quarter of 2007. The FASB's objective in issuing this interpretation is to increase comparability among companies in financial reporting of income taxes. FIN 48 establishes a "more-likely-than-not" recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return, but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. Entergy does not expect that the adoption of FIN 48 will materially affect its financial position, results of operations, or cash flows.

In September 2006, FASB issued SFAS 158, "Employers' Accounting for Defined Benefit Pension and Other Postretirement Plans, an amendment of FASB Statements Nos. 87, 88, 106 and 132(R)," to be effective December 31, 2006. SFAS 158 requires employers to recognize the overfunded or underfunded status of a defined benefit postretirement plan as an asset or liability in its balance sheet with the offset recorded to other comprehensive income. Entergy has previously disclosed its funded status in Note 10 to the consolidated financial statements in the Form 10-K. SFAS 158 also requires that changes in that funded status be recorded in other comprehensive income in the period in which the changes occur. Entergy's Utility business, with the exception of the Louisiana jurisdictions which provide for recovery of other postretirement benefit costs on a pay as you go basis, is generally allowed to recover pension and other postretirement benefit costs each period based upon costs calculated under SFAS 87 and SFAS 106. Entergy's analysis, including the regulatory accounting requirements to support recording the majority of the effect of adoption of SFAS 158 as a regulatory asset, is not yet complete.  Entergy does not expect the implementation of this standard, however, to materially affect Entergy's financial position or results of operations.

__________________________________

 

In the opinion of the management of Entergy Corporation, 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 Utility segment, however, is subject to seasonal fluctuations 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.

 

50

 

ENTERGY ARKANSAS, INC.

MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS

 

Results of Operations

Net Income

Third Quarter 2006 Compared to Third Quarter 2005

Net income decreased slightly primarily due to higher other operation and maintenance expenses, lower net revenue, and lower other income, substantially offset by a lower effective income tax rate.

Nine Months Ended September 30, 2006 Compared to Nine Months Ended September 30, 2005

Net income remained relatively unchanged, increasing $0.9 million in 2006.

Net Revenue

Third Quarter 2006 Compared to Third Quarter 2005

Net revenue, which is Entergy Arkansas' measure of gross margin, 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 third quarter of 2006 to the third quarter of 2005.

 

 

Amount

 

 

(In Millions)

 

 

 

2005 net revenue

 

$325.2  

Pass-through rider revenue

 

27.4 

Net wholesale revenue

 

(8.3)

Other

 

(0.2)

2006 net revenue

 

$344.1  

The pass-through rider revenue variance is primarily due to a change in 2006 in the accounting for city franchise tax revenues as directed by the APSC. The change results in an increase in rider revenue with a corresponding increase in taxes other than income taxes, resulting in no effect on net income.

The net wholesale variance is primarily due to an October 2006 FERC order requiring Entergy Arkansas to make a refund to a coal plant co-owner as a result of a contract dispute. Refer to Note 2 to the domestic utility companies and System Energy financial statements for further discussion of the FERC's decision.

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

Gross operating revenues increased primarily due to:

 

51

 

The increase was partially offset by:

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

Other regulatory charges decreased primarily due to:

Nine Months Ended September 30, 2006 Compared to Nine Months Ended September 30, 2005

Net revenue, which is Entergy Arkansas' measure of gross margin, 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, 2006 to the nine months ended September 30, 2005.

 

 

Amount

 

 

(In Millions)

 

 

 

2005 net revenue

 

$815.1  

Pass-through rider revenue

 

27.4 

Volume/weather

 

13.1 

Capacity costs

 

(11.1)

Deferred fuel cost revisions

 

(6.1)

Other

 

(2.8)

2006 net revenue

 

$835.6  

The pass-through rider revenue variance is primarily due to a change in 2006 in the accounting for city franchise tax revenues as directed by the APSC. The change results in an increase in rider revenue with a corresponding increase in taxes other than income taxes, resulting in no effect on net income.

The volume/weather variance is primarily due to an increase in electricity usage, including the effect of more favorable weather during the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005. Billed electricity usage increased a total of 552 GWh in all sectors.

The capacity costs variance is primarily due to higher capacity-related costs including the revision of reserve equalization payments among Entergy companies due to a FERC ruling regarding the inclusion of interruptible loads in reserve equalization calculations.

The deferred fuel cost revisions variance is primarily due to the 2004 energy cost recovery true-up, made in the first quarter of 2005, which increased net revenue by $4 million.

52

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

Gross operating revenues increased primarily due to:

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

Other regulatory charges decreased primarily due to:

Other Income Statement Variances

Third Quarter 2006 Compared to Third Quarter 2005

Other operation and maintenance expenses increased primarily due to:

Taxes other than income taxes increased primarily due to an increase in city franchise tax expense due to a change in 2006 in the accounting for city franchise tax revenues as directed by the APSC. The change results in an increase in taxes other than income taxes with a corresponding increase in rider revenue, resulting in no effect on net income.

Other income decreased primarily due to proceeds of $4.9 million received in 2005 from the radwaste settlement which is discussed in "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Central States Compact Claim" in the Form 10-K.

53

Nine Months Ended September 30, 2006 Compared to Nine Months Ended September 30, 2005

Other operation and maintenance expenses increased primarily due to:

Taxes other than income taxes increased primarily due to an increase in city franchise tax expense due to a change in 2006 in the accounting for city franchise tax revenues as directed by the APSC. The change results in an increase in taxes other than income taxes with a corresponding increase in rider revenue, resulting in no effect on net income.

Depreciation and amortization expenses increased primarily due to an increase in plant in service and a revision in 2005 of estimated depreciable lives involving certain intangible assets.

Other income decreased primarily due to proceeds of $4.9 million received in 2005 from the radwaste settlement which is discussed in "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Central States Compact Claim" in the Form 10-K.

Income Taxes

The effective income tax rates for the third quarters of 2006 and 2005 were 13.8% and 37.4%, respectively. The effective income tax rates for the nine months ended September 30, 2006 and 2005 were 19.7% and 36.9%, respectively. The difference in the effective income tax rate for the third quarter of 2006 and the nine months ended September 30, 2006 versus the federal statutory rate of 35.0% is primarily due to the flow-through of a pension item. The difference in the effective income tax rate for the third quarter of 2005 versus the federal statutory rate of 35.0% is primarily due to state income taxes, partially offset by book and tax differences related to utility plant items and the amortization of investment tax credits. The difference in the effective income tax rate for the nine months ended September 30, 2005 versus the federal statutory rate of 35.0% is primarily due to state income taxes, partially offset by a downward revision in the estimate of federal income tax expense related to tax depreciation, the amortization of investment tax credits, and book and tax differences related to the allowance for equity funds used during construction.

54

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2006 and 2005 were as follows:

 

 

2006

 

2005

 

 

(In Thousands)

 

 

 

 

 

Cash and cash equivalents at beginning of period

 

$9,393 

 

$89,744 

 

 

 

 

 

Cash flow provided by (used in):

 

 

 

 

 

Operating activities

 

379,580 

 

361,952 

 

Investing activities

 

(205,230)

 

(312,096)

 

Financing activities

 

(164,843)

 

(124,746)

Net increase (decrease) in cash and cash equivalents

 

9,507 

 

(74,890)

 

 

 

 

 

Cash and cash equivalents at end of period

 

$18,900 

 

$14,854  

Operating Activities

Cash flow from operations increased $17.6 million for the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005 primarily due to increased recovery of deferred fuel costs and income tax refunds of $23.9 million in 2006 compared to income tax payments of $33.8 million in 2005. These increases were partially offset by an increase of $110.5 million in pension contributions.

In the first quarter of 2006, Entergy Corporation received an income tax refund as a result of net operating loss carryback provisions contained in the Gulf Opportunity Zone Act of 2005, as discussed in Note 3 to the domestic utilities companies and System Energy financial statements in the Form 10-K. In accordance with Entergy's intercompany tax allocation agreement, in April 2006 Entergy Corporation distributed $12 million of the refund to Entergy Arkansas.

Investing Activities

Net cash flow used in investing activities decreased $106.9 million for the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005 primarily due to a decrease of $107.5 million in other regulatory investments that resulted from fuel cost under-recoveries that have been deferred and are expected to be recovered over a period greater than twelve months.

Financing Activities

Net cash flow used in financing activities increased $40.1 million for the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005 primarily due to:

The increase was partially offset by the net retirement of $54.8 million of long-term debt in 2005.

See " Uses and Sources of Capital " below for the details of Entergy Arkansas' preferred stock activity in 2006.

55

Capital Structure

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

 

 

September 30,
2006

 

December 31,
2005

 

 

 

 

 

Net debt to net capital

 

46.8%

 

47.4%

Effect of subtracting cash from debt

 

0.3%

 

0.1%

Debt to capital

 

47.1%

 

47.5%

Net debt consists of debt less cash and cash equivalents. Debt consists of notes payable, capital lease obligations, and long-term debt, including the currently maturing portion. Capital consists of debt and shareholders' equity. Net capital consists of capital less cash and cash equivalents. Entergy Arkansas uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Arkansas' financial condition.

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' uses and sources of capital. Following are updates to the information provided in the Form 10-K.

In March 2006, Entergy Arkansas issued 3,000,000 shares of $25 par value 6.45% Series Preferred Stock. The dividends are cumulative and payable quarterly beginning July 1, 2006. The preferred stock is redeemable on or after April 1, 2011, at Entergy Arkansas' option, at the call price of $25 per share. In April 2006, Entergy Arkansas used the proceeds from this issuance to redeem the following preferred stock:

Series of Entergy Arkansas Preferred Stock

 

Redemption Price Per Share

     

7.32% Preferred Stock, Cumulative, $100.00 par value

 

$103.17

7.80% Preferred Stock, Cumulative, $100.00 par value

 

$103.25

7.40% Preferred Stock, Cumulative, $100.00 par value

 

$102.80

7.88% Preferred Stock, Cumulative, $100.00 par value

 

$103.00

$1.96 Preferred Stock, Cumulative, $0.01 par value

 

$ 25.00

In April 2006, Entergy Arkansas renewed its $85 million credit facility through April 30, 2007. The facility is no longer subject to a combined borrowing limit with Entergy Louisiana's credit facility. The $85 million credit facility requires that Entergy Arkansas maintain total shareholders' equity of at least 25% of its total assets. There were no outstanding borrowings under the Entergy Arkansas credit facility as of September 30, 2006.

In June 2006, Entergy Arkansas issued $54.7 million of 4.60% Series of Jefferson County bonds due October 2017. The proceeds were used to redeem, prior to maturity, $45.5 million of 5.6% Series of Jefferson County bonds and $9.2 million of 6.3% Series of Jefferson County bonds in July 2006. The issuance is shown as a non-cash transaction on the cash flow statement since the proceeds were placed in a trust and never held as cash by Entergy Arkansas.

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

September 30,
2006

 

December 31,
2005

 

September 30,
2005

 

December 31,
2004

(In Thousands)

 

 

 

 

 

 

 

$19,659

 

($27,346)

 

$31,277

 

$23,561

56

The Pension Protection Act of 2006

The Pension Protection Act of 2006 was signed by the President on August 17, 2006. The intent of the legislation is to require companies to fund 100% of their pension liability; and then for companies to fund, on a going-forward basis, an amount generally estimated to be the amount that the pension liability increases each year due to an additional year of service by the employees eligible for pension benefits. The legislation requires that funding shortfalls be eliminated by companies over a seven-year period, beginning in 2008.

The Pension Protection Act also extended the provisions of the Pension Funding Equity Act that would have expired in 2006 had the Pension Protection Act not been enacted, which increased the allowed discount rate used to calculate the pension funding liability. Entergy Arkansas is in the process of evaluating the effects of the new legislation, but expects that the implementation of the Pension Protection Act will not result in annual pension contributions going-forward that are materially higher than the levels required in 2005 and 2006.

Significant Factors and Known Trends

See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends " in the Form 10-K for a discussion of utility restructuring, federal regulation and proceedings, market and credit risks, state and local rate regulatory risks, nuclear matters, and environmental risks.

In March 2006, Entergy Arkansas filed with the APSC its annual redetermination of the energy cost rate for application to the period April 2006 through March 2007. The filed energy cost rate of $0.02827 per kWh was proposed to replace the interim rate of $0.01900 per kWh that had been in place since October 2005. The interim energy cost rate is discussed in Note 2 to the financial statements in the Form 10-K, along with the investigation that the APSC commenced concerning Entergy Arkansas' interim energy cost rate. The increase in the energy cost rate is due to increases in the cost of purchased power primarily due to the natural gas cost increase and the effect that Hurricanes Katrina and Rita had on market conditions, increased demand for purchased power during the ANO 1 refueling and steam generator replacement outage in the fall of 2005, and coal plant generation curtailments during off-peak periods due to railroad delivery problems.

On March 31, 2006, the APSC suspended implementation of the $0.02827 per kWh energy cost rate, and ordered that the $0.01900 per kWh interim rate remain in effect pending the APSC proceedings on the energy cost recovery filings. The APSC also extended its investigation into Entergy Arkansas' interim energy cost rate to cover the costs included in Entergy Arkansas' March 2006 filing. The extended investigation did not identify new issues in addition to the four issues listed in the Form 10-K and covers the same time period. On April 7, 2006, the APSC issued a show cause order in the investigation proceeding that ordered Entergy Arkansas to file a cost of service study by June 8, 2006. The order also directed Entergy Arkansas to file testimony to support the cost of service study, to support the $0.02827 per kWh cost rate, and to address the general topic of elimination of the energy cost recovery rider.

In June 2006, Entergy Arkansas filed a motion with the APSC seeking again to implement the redetermined energy cost rate of $0.02827 per kWh. After a hearing, the APSC approved Entergy Arkansas' request and the redetermined rate was implemented in July 2006, subject to refund pending the outcome of the APSC energy cost recovery investigation. Because of the delay in implementing the redetermined energy cost rate, Entergy Arkansas estimated in its motion that $46 million of energy costs would remain under-recovered at December 31, 2006.

On June 7, 2006, Entergy Arkansas filed a cost of service study and testimony supporting the redetermined energy cost rate and testimony addressing the prospective elimination of the energy cost recovery rider as ordered by the APSC. A hearing was held in the APSC energy cost recovery investigation on October 12, 2006 and post-hearing briefs were filed by Entergy Arkansas, the APSC General Staff, the Arkansas Attorney General, and the Arkansas Electric Energy Consumers. No party recommended termination of the energy cost recovery rider in the fuel cost investigation proceeding. The timing of a decision in this proceeding is uncertain.

57

In August 2006, Entergy Arkansas filed with the APSC a request for a change in base rates. Entergy Arkansas requested a general base rate increase of $150 million (using an ROE of 11.25%), as well as recovery of FERC-allocated costs pursuant to the FERC decision on the System Agreement. Entergy Arkansas also requested a capacity management rider to recover incremental capacity costs. A procedural schedule has been established with hearings expected to begin in April 2007.

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - System Agreement Litigation " for a discussion of Entergy's compliance filing in that proceeding. If the FERC approves the compliance tariff as filed, then payments under that tariff will be classified as energy costs, which would then be included in setting the retail energy cost rate as part of the normal working of the energy cost recovery rider.  As noted above, the APSC has given notice that it is considering the prospective elimination of the energy cost recovery rider.  Therefore, Entergy Arkansas proposed in the August 2006 base rate case an alternative to the energy cost recovery rider for recovery of the costs allocated to it as a result of the System Agreement litigation should the energy cost recovery rider be lawfully terminated by the APSC.  A separate exact recovery rider, similar to the energy cost recovery rider, would ensure that Entergy Arkansas customers pay only the amount allocated by the FERC.

Federal Regulation

System Agreement Proceedings

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - System Agreement Litigation , APSC Complaint at the FERC , APSC System Agreement Investigation , and MPSC System Agreement Inquiry " for updates regarding proceedings involving the System Agreement.

Independent Coordinator of Transmission (ICT)

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - Independent Coordinator of Transmission " for an update regarding Entergy's ICT proposal.

Available Flowgate Capacity (AFC) Proceeding

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - Available Flowgate Capacity Proceeding " for updates regarding the AFC proceeding at the FERC.

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' accounting for nuclear decommissioning costs, unbilled revenue, and qualified pension and other postretirement benefits.

Recently Issued Accounting Pronouncements

FASB Interpretation No. 48, "Accounting for Uncertainty in Income Taxes" (FIN 48) was issued in July 2006 and is effective for Entergy Arkansas in the first quarter of 2007. The FASB's objective in issuing this interpretation is to increase comparability among companies in financial reporting of income taxes. FIN 48 establishes a "more-likely-than-not" recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return, but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. Entergy Arkansas does not expect that the adoption of FIN 48 will materially affect its financial position, results of operations, or cash flows.

58

In September 2006, FASB issued SFAS 158, "Employers' Accounting for Defined Benefit Pension and Other Postretirement Plans, an amendment of FASB Statements Nos. 87, 88, 106 and 132(R)," to be effective December 31, 2006. SFAS 158 requires employers to recognize the overfunded or underfunded status of a defined benefit postretirement plan as an asset or liability in its balance sheet with the offset recorded to other comprehensive income. Entergy Arkansas has previously disclosed its funded status in Note 10 to the domestic utility companies and System Energy financial statements in the Form 10-K. SFAS 158 also requires that changes in that funded status be recorded in other comprehensive income in the period in which the changes occur. Entergy Arkansas is generally allowed to recover pension and other postretirement benefit costs each period based upon costs calculated under SFAS 87 and SFAS 106. Entergy Arkansas' analysis, including the regulatory accounting requirements to support recording the majority of the effect of the adoption of this standard as a regulatory asset, is not yet complete. Entergy Arkansas does not expect the implementation of this standard, however, to materially affect its financial position or results of operations.

 

59

 

ENTERGY ARKANSAS, INC.
INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2006 and 2005
(Unaudited)
         
    Three Months Ended   Nine Months Ended
    2006   2005   2006   2005
    (In Thousands)   (In Thousands)
                 
OPERATING REVENUES                
Domestic electric   $660,885    $556,445    $1,612,730    $1,373,902 
                 
OPERATING EXPENSES                
Operation and Maintenance:                
  Fuel, fuel-related expenses, and                
   gas purchased for resale   130,942    (25,857)   318,219    57,558 
  Purchased power   186,758    249,023    473,669    496,554 
  Nuclear refueling outage expenses   7,509    7,256    22,235    20,592 
  Other operation and maintenance   120,140     91,719     317,790     283,275  
Decommissioning   7,737    7,566    22,828    23,925 
Taxes other than income taxes   38,489    9,465    57,091    29,353 
Depreciation and amortization   54,547    52,022    161,508    151,822 
Other regulatory charges (credits) - net   (907)   8,121    (14,793)   4,737 
TOTAL   545,215    399,315    1,358,547    1,067,816 
                 
OPERATING INCOME   115,670    157,130    254,183    306,086 
                 
OTHER INCOME                
Allowance for equity funds used during construction   2,242    511    6,060    7,961 
Interest and dividend income   4,972    9,490    16,645    18,860 
Miscellaneous - net   (784)   (598)   (2,356)   (1,277)
TOTAL   6,430    9,403    20,349    25,544 
                 
INTEREST AND OTHER CHARGES  
Interest on long-term debt   19,394    19,002    57,733    59,752 
Other interest - net   650    2,947    3,518    5,171 
Allowance for borrowed funds used during construction   (960)   (2,943)   (2,639)   (6,679)
TOTAL   19,084    19,006    58,612    58,244 
                 
INCOME BEFORE INCOME TAXES   103,016    147,527    215,920    273,386 
                 
Income taxes   14,204     55,159     42,450     100,797  
                 
NET INCOME   88,812    92,368    173,470    172,589 
                 
Preferred dividend requirements and other   1,718    1,944    5,841    5,832 
                 
EARNINGS APPLICABLE TO                
COMMON STOCK   $87,094    $90,424    $167,629    $166,757 
                 
See Notes to Respective Financial Statements.                
                 

60

 

ENTERGY ARKANSAS, INC.
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2006 and 2005
(Unaudited)
     
    2006   2005
    (In Thousands)
         
OPERATING ACTIVITIES        
Net income   $173,470    $172,589 
Adjustments to reconcile net income to net cash flow provided by operating activities:        
  Reserve for regulatory adjustments   21,323   
  Other regulatory charges (credits) - net   (14,793)   4,737 
  Depreciation, amortization, and decommissioning   184,336    175,747 
  Deferred income taxes and investment tax credits   (105,087)   38,755 
  Changes in working capital:        
    Receivables   (70,335)   (79,907)
    Fuel inventory   (5,389)   (4,728)
    Accounts payable   (28,836)   29,891 
    Taxes accrued   168,985    23,821 
    Interest accrued   3,521    1,814 
    Deferred fuel costs   144,778    1,537 
    Other working capital accounts   11,967    3,088 
  Provision for estimated losses and reserves   (1,396)   (2,749)
  Changes in other regulatory assets   (58,208)   51,251 
  Other   (44,756)   (53,894)
Net cash flow provided by operating activities   379,580    361,952 
         
INVESTING ACTIVITIES        
Construction expenditures   (183,878)   (196,591)
Allowance for equity funds used during construction   6,060    7,961 
Nuclear fuel purchases   (49,269)   (62,404)
Proceeds from sale/leaseback of nuclear fuel   49,027    62,404 
Proceeds from nuclear decommissioning trust fund sales   84,126    156,167 
Investment in nuclear decommissioning trust funds   (91,168)   (163,923)
Change in money pool receivable - net   (19,659)   (7,716)
Other regulatory investments   (469)   (107,994)
Net cash flow used in investing activities   (205,230)   (312,096)
         
FINANCING ACTIVITIES        
Proceeds from the issuance of long-term debt     272,702 
Retirement of long-term debt     (327,516)
Proceeds from the issuance of preferred stock   73,355   
Redemption of preferred stock   (75,885)  
Change in money pool payable - net   (27,346)  
Dividends paid:        
  Common stock   (128,900)   (64,100)
  Preferred stock   (6,067)   (5,832)
Net cash flow used in financing activities   (164,843)   (124,746)
         
Net increase (decrease) in cash and cash equivalents   9,507    (74,890)
         
Cash and cash equivalents at beginning of period   9,393    89,744 
         
Cash and cash equivalents at end of period   $18,900    $14,854 
         
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:        
Cash paid/(received) during the period for:        
  Interest - net of amount capitalized   $48,682    $56,332 
  Income taxes   ($23,883)   $33,766 
         
See Notes to Respective Financial Statements.        

 

61

 

ENTERGY ARKANSAS, INC.
BALANCE SHEETS
ASSETS
September 30, 2006 and December 31, 2005
(Unaudited)
   
  2006   2005
  (In Thousands)
         
CURRENT ASSETS        
Cash and cash equivalents:        
  Cash   $10,095    $9,393 
  Temporary cash investments - at cost,         
   which approximates market   8,805   
     Total cash and cash equivalents   18,900    9,393 
Accounts receivable:          
  Customer   146,871    115,321 
  Allowance for doubtful accounts   (14,237)   (15,777)
  Associated companies   73,967    30,902 
  Other   70,025    63,702 
  Accrued unbilled revenues   75,944    68,428 
     Total accounts receivable   352,570    262,576 
Deferred fuel costs   59,873    153,136 
Accumulated deferred income taxes   5,002   
Fuel inventory - at average cost   17,731    12,342 
Materials and supplies - at average cost   95,105    87,875 
Deferred nuclear refueling outage costs   17,076    30,967 
Prepayments and other   8,296    9,628 
TOTAL   574,553    565,917 
         
OTHER PROPERTY AND INVESTMENTS        
Investment in affiliates - at equity   11,206    11,206 
Decommissioning trust funds   422,887    402,124 
Non-utility property - at cost (less accumulated depreciation)   1,447    1,449 
Other   2,976    2,976 
TOTAL   438,516    417,755 
         
UTILITY PLANT        
Electric   6,481,944    6,344,435 
Property under capital lease   5,969    9,900 
Construction work in progress   166,567    139,208 
Nuclear fuel under capital lease   104,859    92,181 
Nuclear fuel   21,519    22,616 
TOTAL UTILITY PLANT   6,780,858    6,608,340 
Less - accumulated depreciation and amortization   2,974,167    2,843,904 
UTILITY PLANT - NET   3,806,691    3,764,436 
         
DEFERRED DEBITS AND OTHER ASSETS        
Regulatory assets:        
  SFAS 109 regulatory asset - net   115,187    61,236 
  Other regulatory assets   465,152    461,015 
  Deferred fuel costs     51,046 
Other   45,202     46,605  
TOTAL   625,541    619,902 
         
TOTAL ASSETS   $5,445,301    $5,368,010 
         
See Notes to Respective Financial Statements.        
 
62
 
ENTERGY ARKANSAS, INC.
BALANCE SHEETS
LIABILITIES AND SHAREHOLDERS' EQUITY
September 30, 2006 and December 31, 2005
(Unaudited)
   
  2006   2005
  (In Thousands)
 
CURRENT LIABILITIES        
Accounts payable:        
  Associated companies   $66,376   $135,357
  Other   129,454   120,090
Customer deposits   48,691   45,432
Taxes accrued   25,623   -
Accumulated deferred income taxes   -   56,186
Interest accrued   22,728   19,207
Obligations under capital leases   48,295   46,857
Other   26,024   21,836
TOTAL   367,191   444,965
         
NON-CURRENT LIABILITIES        
Accumulated deferred income taxes and taxes accrued   1,265,659   1,105,712
Accumulated deferred investment tax credits   60,876   64,001
Obligations under capital leases   62,290   55,224
Other regulatory liabilities   90,229   76,507
Decommissioning   464,943   442,115
Accumulated provisions   27,677   29,073
Long-term debt   1,304,155   1,298,238
Other   220,869   306,034
TOTAL   3,496,698   3,376,904
         
Commitments and Contingencies        
         
SHAREHOLDERS' EQUITY        
Preferred stock without sinking fund   116,350   116,350
Common stock, $0.01 par value, authorized 325,000,000        
 shares; issued and outstanding 46,980,196 shares in 2006        
 and 2005   470   470
Paid-in capital   588,529   591,102
Retained earnings   876,063   838,219
TOTAL   1,581,412   1,546,141
         
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY   $5,445,301   $5,368,010
         
See Notes to Respective Financial Statements.        
         

63

 

ENTERGY ARKANSAS, INC.
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2006 and 2005
(Unaudited)
 
 
    Three Months Ended   Increase/    
Description   2006   2005   (Decrease)   %
    (Dollars In Millions)    
Electric Operating Revenues:                
  Residential   $ 265   $ 217   $ 48    22 
  Commercial   144   107   37    35 
  Industrial   140   108   32    30 
  Governmental   6   5     20 
     Total retail   555   437   118    27 
  Sales for resale                
    Associated companies   70   52   18    35 
    Non-associated companies   29   58   (29)   (50)
  Other   7   9   (2)   (22)
     Total   $ 661   $ 556   $ 105    19 
                 
Billed Electric Energy                
 Sales (GWh):                
  Residential   2,550   2,550    
  Commercial   1,792   1,773   19   
  Industrial   2,112   2,046   66   
  Governmental   81   86   (5)   (6)
     Total retail   6,535   6,455   80   
  Sales for resale                
    Associated companies   1,680   901   779    86 
    Non-associated companies   714   1,077   (363)   (34)
     Total   8,929   8,433   496   
                 
                 
    Nine Months Ended   Increase/    
Description   2006   2005   (Decrease)   %
    (Dollars In Millions)    
Electric Operating Revenues:                
  Residential   $ 554   $ 476   $ 78    16 
  Commercial   315   257   58    23 
  Industrial   323   264   59    22 
  Governmental   15   13     15 
     Total retail   1,207   1,010   197    20 
  Sales for resale                
    Associated companies   253   157   96    61 
    Non-associated companies   113   158   (45)   (28)
  Other   40   49   (9)   (18)
     Total   $ 1,613   $ 1,374   $ 239    17 
                 
Billed Electric Energy                
 Sales (GWh):                
  Residential   6,052   5,921   131   
  Commercial   4,462   4,327   135   
  Industrial   5,727   5,430   297   
  Governmental   209   220   (11)   (5)
     Total retail   16,450   15,898   552   
  Sales for resale                
    Associated companies   5,977   3,877   2,100    54 
    Non-associated companies   2,245   3,249   (1,004)   (31)
     Total   24,672   23,024   1,648   
                 
                 

64

ENTERGY GULF STATES, INC.

MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS

 

Hurricane Rita and Hurricane Katrina

See the Form 10-K for a discussion of the effects of Hurricanes Katrina and Rita, which hit Entergy Gulf States' service territory in the Texas and Louisiana jurisdictions in August and September 2005. The storms resulted in power outages, significant damage to electric distribution, transmission, and generation and gas infrastructure, and the loss of sales and customers due to mandatory evacuations. Following is an update to the discussion in the Form 10-K.

Entergy Gulf States currently estimates that its total restoration costs for the repair or replacement of its electric and gas facilities damaged by Hurricanes Katrina and Rita and business continuity costs will be $633 million, the majority of which is due to Hurricane Rita.

Entergy Gulf States has received $18.9 million thus far on its insurance claims.

As discussed in the Form 10-K, a federal hurricane aid package became law that includes funding for Community Development Block Grants (CDBG) that allows state and local leaders to fund individual recovery priorities. The law permits funding for infrastructure restoration. It is uncertain how much funding, if any, will be designated for utility reconstruction and the timing of such decisions is also uncertain. In September 2006, Entergy Gulf States presented a revised CDBG request to the Louisiana Recovery Authority's Infrastructure Committee. The updated request of $183 million includes estimated spending necessary to complete restoration in Louisiana net of estimated insurance proceeds. The Louisiana Recovery Authority did not act on Entergy Gulf States' request at its October 2006 meeting, and as discussed below, Entergy Gulf States continues to pursue other means of recovering its storm costs.

Storm Costs Recovery Filings with Retail Regulators

On July 31, 2006, Entergy Louisiana and Entergy Gulf States filed a supplemental and amending storm cost recovery application with the LPSC, in which Entergy Louisiana and Entergy Gulf States requested that the LPSC (1) review Entergy Louisiana's and Entergy Gulf States' testimony and exhibits relating to the costs associated with Hurricanes Katrina and Rita, and declare that those verified, actual storm-related costs through May 31, 2006 are $466.8 million for Entergy Louisiana and $200.3 million for Entergy Gulf States in the Louisiana jurisdiction and that those costs were prudently incurred; (2) declare that the annual revenue requirements associated with the recovery of those costs, including carrying costs, based on a ten-year levelized rate are $54.4 million for Entergy Louisiana and $26.2 million for Entergy Gulf States; (3) authorize Entergy Louisiana and Entergy Gulf States to recover the costs through Storm Cost Recovery Riders (SCRRs) proposed by Entergy Louisiana and Entergy Gulf States; (4) declare that the storm costs incurred subsequent to May 31, 2006 are to be filed by Entergy Louisiana and Entergy Gulf States with the LPSC on an annual basis in connection with their annual formula rate plan (FRP) filings, and that the SCRRs be adjusted annually to reflect such costs and any insurance proceeds or CDBG funds actually received, with the adjusted amounts to be collected through the SCRRs to take effect contemporaneous with the effective date of rate changes under the FRP; (5) declare that the storm-related costs incurred by Entergy Louisiana and Entergy Gulf States meet the conditions set forth in the FRP for exclusion from the sharing provisions in those FRPs and authorize the permanent recovery of storm costs outside of the FRPs adopted by the LPSC for Entergy Louisiana and Entergy Gulf States; and (6) authorize the funding of a storm reserve through securitization sufficient to fund a storm cost reserve of $132 million for Entergy Louisiana and $81 million for Entergy Gulf States. Hearings are scheduled for March 2007. Entergy Gulf States and Entergy Louisiana also intend to pursue securitization options for the storm cost recovery as well, which is authorized by a law signed by the Governor of Louisiana in May 2006.

65

In July 2006, Entergy Gulf States filed an application with the PUCT with respect to the $393.2 million of Hurricane Rita reconstruction costs incurred in its Texas retail jurisdiction through March 31, 2006. The filing asks the PUCT to determine that $393.2 million is the amount of reasonable and necessary hurricane reconstruction costs eligible for securitization and recovery, approve the recovery of carrying costs, and approve the manner in which Entergy Gulf States allocates those costs among its Texas retail customer classes.  If approved, Entergy Gulf States' application will ultimately affect all its retail customers in Texas. Entergy Gulf States' filing does not request recovery of costs through a specific rider on customer bills or through any other means at this time. This is the first of two filings authorized by a law passed earlier this year in a special session of the Texas Legislature. A hearing before the PUCT on the filing was scheduled for November 1-3, 2006, but at the commencement of the hearing all of the parties in attendance announced that they had reached a unanimous agreement in principle to settle the issues in the proceeding. The parties are developing the documentation to formalize the settlement. The parties intend to submit the settlement documents to the PUCT prior to Thanksgiving 2006 so that the PUCT can approve them by early December 2006. A second filing will request securitization and recovery of the costs eligible for securitization through retail rates and tariffs. Entergy Gulf States expects to make the second filing following the conclusion of the reconstruction cost case.

Results of Operations

Net Income

Third Quarter 2006 Compared to Third Quarter 2005

Net income decreased $34.7 million primarily due to higher other operation and maintenance expenses, higher taxes other than income taxes, lower other income, and higher interest and other charges.

Nine Months Ended September 30, 2006 Compared to Nine Months Ended September 30, 2005

Net income decreased slightly by $5.5 million primarily due to higher other operation and maintenance expenses, higher taxes other than income taxes, and higher interest and other charges, substantially offset by higher net revenue.

Net Revenue

Third Quarter 2006 Compared to Third Quarter 2005

Net revenue, which is Entergy Gulf States' measure of gross margin, 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 third quarter of 2006 to the third quarter of 2005.

 

 

Amount

 

 

(In Millions)

 

 

 

2005 net revenue

 

$362.0 

Base revenues

 

19.5 

Volume/weather

 

10.5 

Net wholesale revenue

 

9.0 

Reserve equalization

 

6.1 

Price applied to unbilled electric sales

 

(28.4)

Fuel recovery

 

(11.4)

Purchased power capacity

 

(9.2)

Other

 

5.9 

2006 net revenue

 

$364.0 

66

Base revenues increased due to increases in both the Louisiana and Texas jurisdictions. The increases in the Louisiana jurisdiction were effective in October 2005 for the 2004 formula rate plan filing and the annual revenue requirement related to the purchase of power from the Perryville generating station and in September 2006 for the 2005 formula rate plan filing that includes the recovery of incremental deferred and ongoing capacity requirement. The increases in the Texas jurisdiction are related to an incremental purchased capacity recovery rider that began in December 2005 and a transition to competition rider that began in March 2006. Refer to Note 2 to the domestic utility companies and System Energy financial statements and " State and Local Rate Regulation " herein for further discussion of the rate increases.

The volume/weather variance is primarily due to an increase in electricity usage, primarily during the unbilled sales period. The increase in usage was slightly offset by less favorable weather compared to the same period in 2005.

The net wholesale revenue variance is primarily due to increased volume and higher margins on sales to municipal and co-op customers.

The reserve equalization variance is due to lower payments in 2006 as a result of resource plan capacity purchases effective February 2006 which reduced the amount of system-wide capacity allocated to Entergy Gulf States.

The price applied to unbilled electric sales variance is due to the exclusion in 2006 of the fuel cost component in the calculation of the price applied to unbilled sales. Effective January 1, 2006, the fuel cost component is no longer included in the unbilled revenue calculation, which is in accordance with regulatory treatment. Entergy Gulf States expects that the effect of this factor will be a decrease in net revenue of approximately $40 million in its annual results for 2006. See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates " herein for a discussion of the accounting for unbilled revenues.

The fuel recovery variance resulted primarily from the under-recovery in the third quarter of 2006 of fuel costs from retail customers compared to the over-recovery in the third quarter of 2005.

The purchased power capacity variance is primarily due to higher capacity charges primarily associated with power purchases from the Perryville generating station and new purchased power contracts in 2006. A portion of the higher charges is due to the amortization of deferred capacity costs and is offset in base revenues due to base rate increases implemented to recover incremental deferred and ongoing purchased power capacity charges, as discussed above.

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

Gross operating revenues increased primarily due to an increase in fuel cost recovery revenues of $88 million due to higher fuel rates.

Fuel and purchased power expenses increased primarily as a result of higher fuel rates partially offset by decreases in the average market prices of natural gas and purchased power.

Other regulatory charges increased primarily due to:

67

Nine Months Ended September 30, 2006 Compared to Nine Months Ended September 30, 2005

Net revenue, which is Entergy Gulf States' measure of gross margin, 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, 2006 to the nine months ended September 30, 2005.

 

 

Amount

 

 

(In Millions)

 

 

 

2005 net revenue

 

$906.5 

Base revenues

 

50.0 

Volume/weather

 

30.8 

Net wholesale revenue

 

22.3 

Fuel recovery

 

18.2 

Reserve equalization

 

11.5 

Price applied to unbilled electric sales

 

(48.5)

Purchased power capacity

 

(26.7)

Other

 

21.5 

2006 net revenue

 

$985.6 

Base revenues increased due to increases in both the Louisiana and Texas jurisdictions. The increases in the Louisiana jurisdiction were effective in October 2005 for the 2004 formula rate plan filing and the annual revenue requirement related to the purchase of power from the Perryville generating station and in September 2006 for the 2005 formula rate plan filing that includes the recovery of incremental deferred and ongoing capacity requirement. The increases in the Texas jurisdiction are related to an incremental purchased capacity recovery rider that began in December 2005 and a transition to competition rider that began in March 2006. Refer to Note 2 to the domestic utility companies and System Energy financial statements and " State and Local Rate Regulation " herein for further discussion of the rate increases.

The volume/weather variance is due to increased weather-adjusted electricity usage on billed sales in addition to an increase in usage during the unbilled sales period. Weather-adjusted usage increased a total of 402 GWh in the residential and commercial sectors and decreased 202 GWh in the industrial sector.

The net wholesale revenue variance is primarily due to increased volume and higher margins on sales to municipal and co-op customers.

The fuel recovery variance resulted primarily from adjustments of fuel clause recoveries in Entergy Gulf States' Louisiana jurisdiction. The variance is also due to the under-recovery in 2005 of fuel costs from retail customers and increased fuel cost recovery in 2006 as a result of special rate contracts.

The reserve equalization variance is due to lower payments in 2006 as a result of resource plan capacity purchases effective February 2006 and power purchases from the Perryville generating station effective July 2005 both of which reduced the amount of system-wide capacity allocated to Entergy Gulf States.

The price applied to unbilled electric sales variance is due to the exclusion in 2006 of the fuel cost component in the calculation of the price applied to unbilled sales. Effective January 1, 2006, the fuel cost component is no longer included in the unbilled revenue calculation, which is in accordance with regulatory treatment. Entergy expects that the effect of this factor will be a decrease in net revenue of approximately $40 million in its annual results for 2006. See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates " herein for a discussion of the accounting for unbilled revenues.

68

The purchased power capacity variance is primarily due to an increase in capacity charges primarily associated with power purchases from the Perryville generating station in addition to new purchased power contracts in 2006. A portion of the increase in purchased power capacity costs is offset in base revenues due to base rate increases implemented to recover incremental deferred and ongoing purchased power capacity charges, as discussed above.

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

Gross operating revenues increased primarily due to an increase of $356 million in fuel cost recovery revenues due to higher fuel rates and higher volume.

Fuel and purchased power expenses increased primarily due to an increase in deferred fuel expense due to higher fuel rates partially offset by decreases in the average market prices of natural gas and purchased power.

Other regulatory charges increased primarily due to:

Partially offsetting the increase was a regulatory credit of $4.5 million recorded during the second quarter of 2006 as a result of Entergy Gulf States reinstating the application of regulatory accounting principles to its wholesale business. Refer to " Application of SFAS 71 " in Note 7 to the domestic utility companies and System Energy financial statements for further discussion.

Other Income Statement Variances

Third Quarter 2006 Compared to Third Quarter 2005

Other operation and maintenance expenses increased primarily due to:

Taxes other than income taxes increased primarily due to higher Louisiana local franchise taxes primarily due to higher gross revenues as discussed above.

Other income decreased primarily due to proceeds of $3.4 million received July 2005 from the radwaste settlement which is discussed in " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Central States Compact Claim " in the Form 10-K. Also contributing to the decrease was a decrease of $2.0 million in allowance for equity funds used during construction as a result of lower storm-related construction work in progress in 2006.

Interest and other charges increased primarily due to the increase in long-term debt outstanding as a result of the funding of the storm restoration costs resulting from Hurricanes Katrina and Rita.

69

Nine Months Ended September 30, 2006 Compared to Nine Months Ended September 30, 2005

Other operation and maintenance expenses increased primarily due to:

Taxes other than income taxes increased primarily due to higher Louisiana local franchise taxes primarily due to higher gross revenues as discussed above.

Other income which remained relatively unchanged includes the following:

Interest and other charges increased primarily due to the increase in long-term debt outstanding as a result of the funding of the storm restoration costs resulting from Hurricanes Katrina and Rita.

Income Taxes

The effective income tax rates for the third quarters of 2006 and 2005 were 37.5% and 35.8%, respectively. The difference in the effective income tax rate for the third quarter of 2006 versus the federal statutory rate of 35% is primarily due to state income taxes and book and tax differences related to utility plant items partially offset by the amortization of investment tax credits and the flow-through of a pension item.

The effective income tax rates for the nine months ended September 30, 2006 and 2005 were 35.7% and 34.6%, respectively. The effective income tax rate for the nine months ended September 30, 2006 includes increases related to state income taxes and book and tax differences related to utility plant items partially offset by the amortization of investment tax credits, book and tax differences related to the allowance for equity funds used during construction, and the flow-through of a pension item.

 

70

 

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2006 and 2005 were as follows:

 

 

2006

 

2005

 

 

(In Thousands)

 

 

 

 

 

Cash and cash equivalents at beginning of period

 

$25,373 

 

$6,974 

 

 

 

 

 

Cash flow provided by (used in):

 

 

 

 

 

Operating activities

 

514,774 

 

102,311 

 

Investing activities

 

(323,392)

 

(305,177)

 

Financing activities

 

(172,158)

 

199,406 

Net increase (decrease) in cash and cash equivalents

 

19,224 

 

(3,460)

 

 

 

 

 

Cash and cash equivalents at end of period

 

$44,597 

 

$3,514 

Operating Activities

Cash flow from operations increased $412.5 million for the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005 primarily due to:

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

In the first quarter 2006, Entergy Corporation received an income tax refund as a result of net operating loss carryback provisions contained in the Gulf Opportunity Zone Act of 2005, as discussed in Note 3 to the domestic utilities companies and System Energy financial statements in the Form 10-K. In accordance with Entergy's intercompany tax allocation agreement, in April 2006 Entergy Corporation distributed $23 million of the refund to Entergy Gulf States.

Investing Activities

Net cash used in investing activities increased $18.2 million for the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005 primarily due to an increase in construction expenditures of $100.8 million due to storm-related projects partially offset by a decrease in under-recovered fuel and purchased power expenses of $86.9 million in Texas that have been deferred and are expected to be collected over a period greater than twelve months.

Financing Activities

Entergy Gulf States used $172.2 million in financing activities for the nine months ended September 30, 2006 compared to providing $199.4 million for the nine months ended September 30, 2005 primarily due to:

 

71

 

Capital Structure

Entergy Gulf States' capitalization is balanced between equity and debt, as shown in the following table.

 

 

September 30,
2006

 

December 31,
2005

 

 

 

 

 

Net debt to net capital

 

51.3%

 

51.4%

Effect of subtracting cash from debt

 

0.5%

 

0.3%

Debt to capital

 

51.8%

 

51.7%

Net debt consists of debt less cash and cash equivalents. Debt consists of notes payable, capital lease obligations, preferred stock with sinking fund, and long-term debt, including the currently maturing portion. Capital consists of debt and shareholders' equity. Net capital consists of capital less cash and cash equivalents. Entergy Gulf States 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' financial condition.

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' uses and sources of capital. Following are updates to the information provided in the Form 10-K.

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

September 30,
2006

 

December 31,
2005

 

September 30,
2005

 

December 31,
2004

(In Thousands)

 

 

 

 

 

 

 

$62,356

 

$64,011

 

($112,857)

 

($59,720)

See Note 4 to the domestic utility companies and System Energy financial statements in the Form 10-K for a description of the money pool.

In February 2006, Entergy Gulf States established a $25 million line of credit and increased the capacity of the credit facility to $50 million in August 2006. The line of credit allows Entergy Gulf States to borrow money and to issue letters of credit. $1.4 million in letters of credit were issued under the facility at September 30, 2006, and no borrowings were outstanding. The line of credit terminates in February 2011.

The Pension Protection Act of 2006

The Pension Protection Act of 2006 was signed by the President on August 17, 2006. The intent of the legislation is to require companies to fund 100% of their pension liability; and then for companies to fund, on a going-forward basis, an amount generally estimated to be the amount that the pension liability increases each year due to an additional year of service by the employees eligible for pension benefits. The legislation requires that funding shortfalls be eliminated by companies over a seven-year period, beginning in 2008.

The Pension Protection Act also extended the provisions of the Pension Funding Equity Act that would have expired in 2006 had the Pension Protection Act not been enacted, which increased the allowed discount rate used to calculate the pension funding liability. Entergy Gulf States is in the process of evaluating the effects of the new legislation, but expects that the implementation of the Pension Protection Act will not result in annual pension contributions going-forward that are materially higher than the levels required in 2005 and 2006.

72

Significant Factors and Known Trends

See " MANAGEMENT ' S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends " in the Form 10-K for a discussion of transition to retail competition, state and local rate regulation, federal regulation and proceedings, the Energy Policy Act of 2005, state and local rate regulatory risk, industrial, commercial, and wholesale customers, market and credit risks, nuclear matters, environmental risks, and litigation risks. Following are updates to the information disclosed in the Form 10-K.

Transition to Retail Competition

Texas

As discussed in the Form 10-K, Entergy Gulf States made a January 2006 filing regarding the identification of power region(s) required by the 2005 legislation, and based on the statutory requirements for the certification of a qualified power region (QPR), previous PUCT rulings, and Entergy Gulf States' geographical location, Entergy Gulf States identified three potential power regions:

  1. Electric Reliability Council of Texas (ERCOT) as the power region and Independent Organization (IO);
  2. Southwest Power Pool (SPP) as the power region and IO; and
  3. the Entergy market as the power region and the Independent Coordinator of Transmission (ICT) as the IO.

Based on previous rulings of the PUCT, and absent reconsideration of those rulings, Entergy Gulf States believes that the third alternative - an ICT operating in Entergy's market area - is not likely to be a viable QPR alternative at this time. Accordingly, while noting this alternative, Entergy Gulf States' filing focuses on the first two alternatives, which are expected to meet the statutory requirements for certification so long as certain key implementation issues can be resolved. Entergy Gulf States' filing enumerated and discussed the corresponding steps and a high-level schedule associated with certifying either of these two power regions.

Entergy Gulf States' filing did not make a recommendation between ERCOT and the SPP as a power region. Rather, the filing discussed the major issues that must be resolved for either of those alternatives to be implemented. In the case of ERCOT, the major issue is the cost and time related to the construction of facilities to interconnect Entergy Gulf States' Texas operations with ERCOT, while addressing the interest of Entergy Gulf States' retail customers and certain wholesale customers in access to generation outside of Texas. With respect to the SPP, the major issue is the development of protocols that would ultimately be necessary to implement retail open access.

Entergy Gulf States recommended that the PUCT open a project for the purpose of involving stakeholders in the selection of the single power region that Entergy Gulf States should request for certification. Entergy Gulf States notes that House Bill 1567 also directs Entergy Gulf States to make a transition to competition filing no later than January 1, 2007. In August 2006, the PUCT staff recommended that Entergy Gulf States be required to provide the information on both the ERCOT option and the SPP option. The PUCT accepted the PUCT staff's recommendation and stated the need for a "robust record" to make a decision on the applicable power region. Entergy Gulf States is working with both ERCOT and the SPP concerning both options, and plans to make another filing with the PUCT before January 2007.

Jurisdictional Separation Plan

See the Form 10-K for a discussion of business and jurisdictional separation plans concerning Entergy Gulf States. In January 2006, the LPSC directed that Entergy Gulf States file a complete jurisdictional separation plan as soon as possible. Therefore, on April 26, 2006, Entergy Gulf States filed its plan for jurisdictional separation with the LPSC and requested that it grant approval no later than September 30, 2006.  The plan provides for Entergy Gulf States to be separated into two vertically integrated utilities, one subject solely to the retail jurisdiction of the LPSC and the other subject solely to the retail jurisdictional of the PUCT. The plan also provides that the Texas utility should own all the distribution and transmission assets located in Texas, the gas-fired generating plants located in Texas, and undivided ownership shares of Entergy Gulf States' 70% interest in Nelson 6 and 42% interest in Big Cajun 2, Unit 3, which are coal-fired generating plants located in Louisiana. The Louisiana utility would own all of

 

73

 

 the remaining assets currently owned by Entergy Gulf States.  The Texas utility would purchase from the Louisiana utility pursuant to a life-of-the unit purchased power agreement (PPA) a share of capacity and energy of River Bend. Each separated utility also would purchase pursuant to a PPA a share of capacity and energy of the gas-fired generating plants owned by the other utility. The PPAs associated with the gas-fired generating plants would terminate when retail open access commences in the Texas utility's service territory. Until that time, each utility will participate in the System Agreement and the Entergy System generation will continue to be dispatched in the same manner as before the jurisdictional separation. Under the provisions of the System Agreement, the Texas utility will terminate its participation in the System Agreement, except for the aspects related to transmission equalization, when Texas implements retail open access for Entergy Gulf States. The plan also provides that the operation of the generating plants will not change as a result of the jurisdictional separation. A hearing was held in September 2006 and this issue is expected to be addressed by the LPSC at its November 29, 2006 meeting. Approvals of the FERC and the NRC may also be required for certain matters before any implementation of the jurisdictional separation of Entergy Gulf States. Although formal approval of the PUCT is not required for implementation of the jurisdictional separation, Entergy Gulf States will seek input from the PUCT and continue to keep it informed of the status of the proceedings.

State and Local Rate Regulation

As discussed in the Form 10-K, in August 2005, Entergy Gulf States filed with the PUCT an application for recovery of its transition to competition costs. Entergy Gulf States requested recovery of $189 million in transition to competition costs through implementation of a 15-year rider to be effective no later than March 1, 2006. The $189 million represents transition to competition costs Entergy Gulf States incurred from June 1, 1999 through June 17, 2005 in preparing for competition in its Texas service area, including attendant AFUDC, and all carrying costs projected to be incurred on the transition to competition costs through February 28, 2006. The $189 million is before any gross-up for taxes or carrying costs over the 15-year recovery period. Entergy Gulf States reached a unanimous settlement agreement on all issues with the active parties in the transition to competition cost recovery case. The agreement allows Entergy Gulf States to recover $14.5 million per year in transition to competition costs over a 15-year period. Entergy Gulf States implemented interim rates based on this revenue level on March 1, 2006. The PUCT approved the settlement agreement in June 2006.

In March 2006, the LPSC approved an uncontested stipulated settlement in Entergy Gulf States' formula rate plan filing for the 2004 test year. The settlement includes a revenue requirement increase of $36.8 million and calls for Entergy Gulf States to apply a refund liability of $0.7 million to capacity deferrals. The refund liability pertained to the periods 2004-2005 as well as the interim period in which a $37.2 million revenue increase was in place.

In May 2006, Entergy Gulf States made its formula rate plan filing with the LPSC for the 2005 test year. Entergy Gulf States modified the filing in August 2006 to reflect an 11.1% return on equity which is within the allowed bandwidth. The modified filing includes a formula rate plan increase of $17.2 million which provides for interim recovery of storm costs from Hurricanes Katrina and Rita and recovery of LPSC-approved incremental deferred and ongoing capacity costs. The increase was implemented, subject to refund, with the first billing cycle of September 2006.

In January 2006, Entergy Gulf States filed with the LPSC its gas rate stabilization plan. The filing showed a revenue deficiency of $4.1 million based on an ROE mid-point of 10.5%. On May 1, 2006, Entergy Gulf States implemented a $3.5 million rate increase pursuant to an uncontested agreement with the LPSC Staff.

Federal Regulation

System Agreement Proceedings

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - System Agreement Litigation , APSC Complaint at the FERC , APSC System Agreement Investigation , and MPSC System Agreement Inquiry " for updates regarding proceedings involving the System Agreement.

74

Independent Coordinator of Transmission (ICT)

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - Independent Coordinator of Transmission " for an update regarding Entergy's ICT proposal.

Available Flowgate Capacity (AFC) Proceeding

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - Available Flowgate Capacity Proceeding " for updates regarding the AFC proceeding at the FERC.

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' accounting for nuclear decommissioning costs, the application of SFAS 71, unbilled revenue, and qualified pension and other postretirement benefits. Following is an update to that discussion.

Unbilled Revenue

As discussed in Note 7 to the domestic utility companies and System Energy financial statements, effective January 1, 2006, the Louisiana portion of Entergy Gulf States reclassified the fuel component of unbilled accounts receivable to deferred fuel and will no longer include the fuel component in its unbilled revenue calculation, which is in accordance with regulatory treatment.

Recently Issued Accounting Pronouncements

FASB Interpretation No. 48, "Accounting for Uncertainty in Income Taxes" (FIN 48) was issued in July 2006 and is effective for Entergy Gulf States in the first quarter of 2007. The FASB's objective in issuing this interpretation is to increase comparability among companies in financial reporting of income taxes. FIN 48 establishes a "more-likely-than-not" recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return, but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. Entergy Gulf States does not expect that the adoption of FIN 48 will materially affect its financial position, results of operations, or cash flows.

In September 2006, FASB issued SFAS 158, "Employers' Accounting for Defined Benefit Pension and Other Postretirement Plans", an amendment of FASB Statements Nos. 87, 88, 106 and 132(R)," to be effective December 31, 2006. SFAS 158 requires employers to recognize the over-funded or under-funded status of a defined benefit postretirement plan as an asset or liability in its balance sheet with the offset recorded to other comprehensive income. Entergy Gulf States has previously disclosed its funded status in Note 10 to the domestic utility companies and System Energy financial statements in the Form 10-K. SFAS 158 also requires that changes in that funded status be recorded in other comprehensive income in the period in which the changes occur. The Texas jurisdiction of Entergy Gulf States is generally allowed to recover pension and other postretirement benefit costs each period based upon costs calculated under SFAS 87 and SFAS 106. The Louisiana jurisdiction of Entergy Gulf States recovers other postretirement benefit costs on a pay as you go basis. Entergy Gulf States' analysis including the regulatory accounting requirements to support recording the majority of the effect of the adoption of this standard as a regulatory asset is not yet complete. Entergy Gulf States does not expect the implementation of this standard, however, to materially affect its financial position or results of operations.

75

ENTERGY GULF STATES, INC.
INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2006 and 2005
(Unaudited)
 
  Three Months Ended   Nine Months Ended
    2006   2005   2006   2005
    (In Thousands)   (In Thousands)
                 
OPERATING REVENUES                
Domestic electric   $1,043,264    $959,498    $2,766,558    $2,358,881 
Natural gas   12,495    12,342    63,521    51,729 
TOTAL   1,055,759    971,840    2,830,079    2,410,610 
                 
OPERATING EXPENSES                
Operation and Maintenance:                
  Fuel, fuel-related expenses, and                
   gas purchased for resale   342,828    212,135    842,959    579,980 
  Purchased power   348,318    399,904    999,244    932,012 
  Nuclear refueling outage expenses   4,199    4,778    13,299    13,374 
  Other operation and maintenance   121,560     91,044     367,113     324,165  
Decommissioning   2,731    2,395    8,028    7,038 
Taxes other than income taxes   40,624    32,660    108,312    92,135 
Depreciation and amortization   53,802    51,851    154,981    151,192 
Other regulatory charges (credits) - net   608    (2,199)   2,246    (7,901)
TOTAL   914,670    792,568    2,496,182    2,091,995 
                 
OPERATING INCOME   141,089    179,272    333,897    318,615 
                 
OTHER INCOME                
Allowance for equity funds used during construction   1,697    3,670    9,498    12,675 
Interest and dividend income   6,336    8,469    20,805    15,318 
Miscellaneous - net   (477)   1,353    (876)   1,979 
TOTAL   7,556    13,492    29,427    29,972 
                 
INTEREST AND OTHER CHARGES  
Interest on long-term debt   35,004    28,397    102,997    84,835 
Other interest - net   1,992    2,907    5,989    7,288 
Allowance for borrowed funds used during construction   (1,027)   (2,134)   (5,428)   (7,637)
TOTAL   35,969    29,170    103,558    84,486 
                 
INCOME BEFORE INCOME TAXES   112,676    163,594    259,766    264,101 
                 
Income taxes   42,268     58,534     92,604     91,405  
                 
NET INCOME   70,408    105,060    167,162    172,696 
                 
Preferred dividend requirements and other   1,009    1,050    3,041    3,176 
                 
EARNINGS APPLICABLE TO                
COMMON STOCK   $69,399    $104,010    $164,121    $169,520 
                 
See Notes to Respective Financial Statements.                
                 

76

 

ENTERGY GULF STATES, INC.
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2006 and 2005
(Unaudited)
     
    2006   2005
    (In Thousands)
         
OPERATING ACTIVITIES        
Net income   $167,162    $172,696 
Adjustments to reconcile net income to net cash flow provided by operating activities:        
  Reserve for regulatory adjustments   6,305    (65,526)
  Other regulatory charges (credits) - net   2,246    (7,901)
  Depreciation, amortization, and decommissioning   163,009    158,230 
  Deferred income taxes and investment tax credits   (59,744)   72,183 
  Changes in working capital:        
    Receivables   89,178    (213,039)
    Fuel inventory   (8,996)   (210)
    Accounts payable   (94,479)   66,491 
    Taxes accrued   223,610    30,295 
    Interest accrued   706    1,178 
    Deferred fuel costs   151,118    (81,043)
    Other working capital accounts   7,854    (17,127)
  Provision for estimated losses and reserves   (4,252)   (929)
  Changes in other regulatory assets   (117,618)   (41,488)
  Other   (11,325)   28,501 
Net cash flow provided by operating activities   514,774    102,311 
         
INVESTING ACTIVITIES        
Construction expenditures   (311,255)   (210,484)
Allowance for equity funds used during construction   9,498    12,675 
Nuclear fuel purchases   (38,357)   (371)
Proceeds from sale/leaseback of nuclear fuel   37,647    481 
Proceeds from nuclear decommissioning trust fund sales   39,344    27,477 
Investment in nuclear decommissioning trust funds   (49,217)   (37,013)
Change in money pool receivable - net   1,655   
Changes in other investments - net   915    2,629 
Other regulatory investments   (13,622)   (100,571)
Net cash flow used in investing activities   (323,392)   (305,177)
         
FINANCING ACTIVITIES        
Proceeds from the issuance of long-term debt     581,037 
Retirement of long-term debt     (366,229)
Redemption of preferred stock   (3,450)   (3,450)
Change in money pool payable - net     53,137 
Dividends paid:        
  Common stock   (165,700)   (61,900)
  Preferred stock   (3,008)   (3,189)
Net cash flow provided by (used in) financing activities   (172,158)   199,406 
         
Net increase (decrease) in cash and cash equivalents   19,224    (3,460)
         
Cash and cash equivalents at beginning of period   25,373    6,974 
         
Cash and cash equivalents at end of period   $44,597    $3,514 
         
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:        
Cash paid/(received) during the period for:        
  Interest - net of amount capitalized   $101,059    $85,109 
  Income taxes   ($54,920)   $14,450 
         
See Notes to Respective Financial Statements.        
         

77

 

ENTERGY GULF STATES, INC.
BALANCE SHEETS
ASSETS
September 30, 2006 and December 31, 2005
(Unaudited)
         
    2006   2005
  (In Thousands)
       
CURRENT ASSETS            
Cash and cash equivalents:            
  Cash       $5,873    $7,341 
  Temporary cash investments - at cost,            
   which approximates market       38,724    18,032 
     Total cash and cash equivalents       44,597    25,373 
Accounts receivable:            
  Customer       207,986    203,205 
  Allowance for doubtful accounts       (2,027)   (4,794)
  Associated companies       99,085    90,223 
  Other       42,032    50,445 
  Accrued unbilled revenues       87,697    186,527 
     Total accounts receivable       434,773    525,606 
Deferred fuel costs       86,773    254,950 
Fuel inventory - at average cost       69,192    60,196 
Materials and supplies - at average cost       118,421    112,544 
Prepayments and other       17,683    36,996 
TOTAL       771,439    1,015,665 
             
OTHER PROPERTY AND INVESTMENTS        
Decommissioning trust funds       331,452    310,779 
Non-utility property - at cost (less accumulated depreciation)       94,038    91,589 
Other       22,700    22,498 
TOTAL       448,190    424,866 
             
UTILITY PLANT        
Electric       8,869,375    8,569,073 
Natural gas       89,266    86,375 
Construction work in progress       156,423    526,017 
Nuclear fuel under capital lease       70,326    55,155 
Nuclear fuel       12,433    11,338 
TOTAL UTILITY PLANT       9,197,823    9,247,958 
Less - accumulated depreciation and amortization       4,136,512    4,075,724 
UTILITY PLANT - NET       5,061,311    5,172,234 
              
DEFERRED DEBITS AND OTHER ASSETS        
Regulatory assets:            
  SFAS 109 regulatory asset - net       479,013    459,136 
  Other regulatory assets       774,004    604,419 
  Deferred fuel costs       100,124    69,443 
Long-term receivables       12,937    16,151 
Other       30,029    41,195 
TOTAL       1,396,107    1,190,344 
             
TOTAL ASSETS       $7,677,047    $7,803,109 
             
See Notes to Respective Financial Statements.            
 
78
 
ENTERGY GULF STATES, INC.
BALANCE SHEETS
LIABILITIES AND SHAREHOLDERS' EQUITY
September 30, 2006 and December 31, 2005
(Unaudited)
   
    2006   2005
  (In Thousands)
 
CURRENT LIABILITIES        
Accounts payable:            
  Associated companies       $93,817    $100,313 
  Other       166,785    479,232 
Customer deposits       66,652    57,756 
Taxes accrued       68,055   
Accumulated deferred income taxes       19,423    71,196 
Nuclear refueling outage costs       4,791    15,548 
Interest accrued       35,044    34,338 
Obligations under capital leases       24,935    33,516 
Other       31,353    14,945 
TOTAL       510,855    806,844 
             
NON-CURRENT LIABILITIES        
Accumulated deferred income taxes and taxes accrued       1,777,795    1,619,890 
Accumulated deferred investment tax credits       128,629    132,909 
Obligations under capital leases       45,391    20,724 
Other regulatory liabilities       46,708    37,482 
Decommissioning and retirement cost liabilities       187,029    175,480 
Transition to competition       79,098    79,098 
Regulatory reserves       15,916    16,153 
Accumulated provisions       67,133    67,747 
Long-term debt       2,358,269    2,358,130 
Preferred stock with sinking fund       10,500    13,950 
Other       180,473    203,665 
TOTAL       4,896,941    4,725,228 
             
Commitments and Contingencies            
             
SHAREHOLDERS' EQUITY        
Preferred stock without sinking fund       47,327    47,327 
Common stock, no par value, authorized 200,000,000             
 shares; issued and outstanding 100 shares in 2006 and 2005       114,055    114,055 
Paid-in capital       1,457,486    1,457,486 
Retained earnings       651,999    653,578 
Accumulated other comprehensive loss       (1,616)   (1,409)
TOTAL       2,269,251    2,271,037 
             
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY       $7,677,047    $7,803,109 
             
See Notes to Respective Financial Statements.            

79

 

ENTERGY GULF STATES, INC.
STATEMENTS OF RETAINED EARNINGS AND COMPREHENSIVE INCOME
For the Three and Nine Months Ended September 30, 2006 and 2005
(Unaudited)
                     
        Three Months Ended
        2006   2005
        (In Thousands)
RETAINED EARNINGS                    
Retained Earnings - Beginning of period       $665,300       $553,092    
                     
  Add: Net Income       70,408   $70,408   105,060   $105,060
                     
  Deduct:                    
    Dividends declared on common stock       82,700       36,300    
    Preferred dividend requirements and other       1,009   1,009   1,050   1,050
        83,709       37,350    
                     
Retained Earnings - End of period       $651,999       $620,802    
                     
ACCUMULATED OTHER COMPREHENSIVE                    
INCOME (LOSS) (Net of Taxes):                    
Balance at beginning of period:                    
  Other accumulated comprehensive income items       ($2,233)       $786    
                     
Net derivative instrument fair value changes                    
 arising during the period       617   617   8   8
                     
Balance at end of period:                    
  Other accumulated comprehensive income items       ($1,616)       $794    
Comprehensive Income           $70,016       $104,018
                     
                     
        Nine Months Ended
        2006   2005
        (In Thousands)
RETAINED EARNINGS                    
Retained Earnings - Beginning of period       $653,578       $513,182    
                     
  Add: Net Income       167,162   $167,162   172,696   $172,696
                     
  Deduct:                    
    Dividends declared on common stock       165,700       61,900    
    Preferred dividend requirements and other       3,041   3,041   3,176   3,176
        168,741       65,076    
                     
Retained Earnings - End of period       $651,999       $620,802    
                     
ACCUMULATED OTHER COMPREHENSIVE                    
INCOME (LOSS) (Net of Taxes):                    
Balance at beginning of period:                    
  Other accumulated comprehensive income items       ($1,409)       $714    
                     
Net unrealized investment gains       (824)       -    
Net derivative instrument fair value changes                    
 arising during the period       617   617   80   80
                     
Balance at end of period:                    
  Other accumulated comprehensive income items       ($1,616)       $794    
Comprehensive Income           $164,738       $169,600
                     
                     
See Notes to Respective Financial Statements.                    

80

 

ENTERGY GULF STATES, INC.
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2006 and 2005
(Unaudited)
 
                 
    Three Months Ended   Increase/    
Description   2006   2005   (Decrease)   %
    (Dollars In Millions)    
Electric Operating Revenues:                
  Residential   $375   $330   $45    14 
  Commercial   249   214   35    16 
  Industrial   288   257   31    12 
  Governmental   13   11     18 
     Total retail   925   812   113    14 
  Sales for resale                
    Associated companies   46   49   (3)   (6)
    Non-associated companies   57   61   (4)   (7)
  Other   15   37   (22)   (59)
     Total   $1,043   $959   $84   
                 
Billed Electric Energy                
 Sales (GWh):                
  Residential   3,393   3,455   (62)   (2)
  Commercial   2,553   2,526   27   
  Industrial   3,920   3,772   148   
  Governmental   118   120   (2)   (2)
     Total retail   9,984   9,873   111   
  Sales for resale                
    Associated companies   1,073   785   288    37 
    Non-associated companies   918   936   (18)   (2)
     Total   11,975   11,594   381   
                 
                 
    Nine Months Ended   Increase/    
Description   2006   2005   (Decrease)   %
    (Dollars In Millions)    
Electric Operating Revenues:                 
  Residential   $874   $700   $174    25 
  Commercial   671   520   151    29 
  Industrial   889   725   164    23 
  Governmental   37   30     23 
     Total retail   2,471   1,975   496    25 
  Sales for resale                
    Associated companies   95   96   (1)   (1)
    Non-associated companies   157   136   21    15 
  Other   44   152   (108)   (71)
     Total   $2,767   $2,359   $408    17 
                 
Billed Electric Energy                
 Sales (GWh):                 
  Residential   7,841   7,734   107   
  Commercial   6,681   6,452   229   
  Industrial   11,430   11,632   (202)   (2)
  Governmental   340   334    
     Total retail   26,292   26,152   140   
  Sales for resale                
    Associated companies   2,225   2,080   145   
    Non-associated companies   2,213   2,200   13   
     Total   30,730   30,432   298   
                 
                 

81

ENTERGY LOUISIANA, LLC

MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS

 

Hurricane Rita and Hurricane Katrina

See the Form 10-K for a discussion of the effects of Hurricanes Katrina and Rita, which caused catastrophic damage to Entergy Louisiana's service territory in August and September 2005, including the effect of extensive flooding that resulted from levee breaks in and around Entergy Louisiana's service territory. Following is an update to the discussion in the Form 10-K.

Entergy Louisiana currently estimates that total restoration costs for the repair and/or replacement of its electric facilities damaged by Hurricanes Katrina and Rita and business continuity costs will be $541 million.

Entergy Louisiana has received $9.9 million thus far on its insurance claims.

As discussed in the Form 10-K, a federal hurricane aid package became law that includes funding for Community Development Block Grants (CDBG) that allows state and local leaders to fund individual recovery priorities. The law permits funding for infrastructure restoration. It is uncertain how much funding, if any, will be designated for utility reconstruction and the timing of such decisions is also uncertain. In September 2006, Entergy Louisiana presented a revised CDBG request to the Louisiana Recovery Authority's Infrastructure Committee. The request of $539 million includes estimated spending necessary to complete restoration net of estimated insurance proceeds. The Louisiana Recovery Authority did not act on Entergy Louisiana's request at its October 2006 meeting, and as discussed below, Entergy Louisiana continues to pursue other means of recovering its storm costs.

Storm Costs Recovery Filing with Retail Regulator

On July 31, 2006, Entergy Louisiana and Entergy Gulf States filed a supplemental and amending storm cost recovery application with the LPSC, in which Entergy Louisiana and Entergy Gulf States requested that the LPSC (1) review Entergy Louisiana's and Entergy Gulf States' testimony and exhibits relating to the costs associated with Hurricanes Katrina and Rita, and declare that those verified, actual storm-related costs through May 31, 2006 are $466.8 million for Entergy Louisiana and $200.3 million for Entergy Gulf States in the Louisiana jurisdiction and that those costs were prudently incurred; (2) declare that the annual revenue requirements associated with the recovery of those costs, including carrying costs, based on a ten-year levelized rate are $54.4 million for Entergy Louisiana and $26.2 million for Entergy Gulf States; (3) authorize Entergy Louisiana and Entergy Gulf States to recover the costs through Storm Cost Recovery Riders (SCRRs) proposed by Entergy Louisiana and Entergy Gulf States; (4) declare that the storm costs incurred subsequent to May 31, 2006 are to be filed by Entergy Louisiana and Entergy Gulf States with the LPSC on an annual basis in connection with their annual formula rate plan (FRP) filings, and that the SCRRs be adjusted annually to reflect such costs and any insurance proceeds or CDBG funds actually received, with the adjusted amounts to be collected through the SCRRs to take effect contemporaneous with the effective date of rate changes under the FRP; (5) declare that the storm-related costs incurred by Entergy Louisiana and Entergy Gulf States meet the conditions set forth in the FRP for exclusion from the sharing provisions in those FRPs and authorize the permanent recovery of storm costs outside of the FRPs adopted by the LPSC for Entergy Louisiana and Entergy Gulf States; and (6) authorize the funding of a storm reserve through securitization sufficient to fund a storm cost reserve of $132 million for Entergy Louisiana and $81 million for Entergy Gulf States. Hearings are scheduled for March 2007. Entergy Gulf States and Entergy Louisiana also intend to pursue securitization options for the storm cost recovery as well, which is authorized by a law signed by the Governor of Louisiana in May 2006.

82

Results of Operations

Net Income

Third Quarter 2006 Compared to Third Quarter 2005

Net income increased $28.9 million primarily due to higher net revenue partially offset by higher other operation and maintenance expenses and lower other income.

Nine Months Ended September 30, 2006 Compared to Nine Months Ended September 30, 2005

Net income increased $8.4 million primarily due to higher net revenue, lower taxes other than income taxes, lower depreciation and amortization expenses, and higher other income, partially offset by higher other operation and maintenance expenses.

Net Revenue

Third Quarter 2006 Compared to Third Quarter 2005

Net revenue, which is Entergy Louisiana's measure of gross margin, 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 of 2006 to the third quarter of 2005.

 

 

Amount

 

 

(In Millions)

 

 

 

2005 net revenue

 

$236.4 

Price applied to unbilled electric sales

 

58.9 

Base revenues

 

14.6 

Volume/weather

 

11.1 

Reserve equalization

 

(9.7)

Purchased power capacity

 

(7.5)

Other

 

0.9 

2006 net revenue

 

$304.7 

The price applied to unbilled electric sales variance is due to the exclusion in 2006 of the fuel cost component in the calculation of the price applied to unbilled sales. Effective January 1, 2006, the fuel cost component is no longer included in the unbilled revenue calculation, which is in accordance with regulatory treatment. Entergy Louisiana expects that the effect of this factor will be an increase in net revenue of approximately $10 million for its annual results for 2006. See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates " herein for a discussion of the accounting for unbilled revenues.

The base revenues variance is primarily due to increases effective September 2006 for the 2005 formula rate plan filing to recover LPSC-approved incremental deferred and ongoing capacity costs. See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - State and Local Regulation " herein for a discussion of the formula rate plan filing.

The volume/weather variance is primarily due to an increase in electricity usage. Billed electricity usage increased a total of 431 GWh in all sectors.

The reserve equalization variance is primarily due to a revision made in 2005 of reserve equalization payments among Entergy companies due to a FERC ruling regarding the inclusion of interruptible loads in reserve equalization calculations.

83

The purchased power capacity variance is primarily due to higher purchased power capacity charges and the amortization of capacity charges effective September 2006 as a result of the formula rate plan filing in May 2006. A portion of the purchased power capacity costs is offset in base revenues due to base rate increases implemented to recover incremental deferred and ongoing purchased power capacity charges, as mentioned above.

Fuel and purchased power expenses and other regulatory credits

Fuel and purchased power expenses decreased primarily due to decreases in the market prices of natural gas and purchased power partially offset by an increase in the recovery from customers of deferred fuel costs.

Other regulatory credits decreased primarily due to the deferral of capacity charges in 2005. The decrease was also due to the amortization of capacity charges in 2006 as a result of the formula rate plan filing in May 2006 with the LPSC to recover such costs through base rates effective September 2006. See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - State and Local Regulation " herein for a discussion of the formula rate plan filing.

Nine Months Ended September 30, 2006 Compared to Nine Months Ended September 30, 2005

Net revenue, which is Entergy Louisiana's measure of gross margin, 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, 2006 to the nine months ended September 30, 2005.

 

 

Amount

 

 

(In Millions)

 

 

 

2005 net revenue

 

$731.9 

Base revenues

 

14.6 

Net wholesale revenue

 

12.8 

Rate refund provisions

 

5.0 

Reserve equalization

 

(13.8)

Volume/weather

 

(12.2)

Price applied to unbilled electric sales

 

(10.4)

Other

 

9.4 

2006 net revenue

 

$737.3 

The base revenues variance is primarily due to increases effective September 2006 for the 2005 formula rate plan filing to recover LPSC-approved incremental deferred and ongoing capacity costs. See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - State and Local Regulation " herein for a discussion of the formula rate plan filing.

The net wholesale revenue variance is primarily due to the sale of 75% of the generation from the Perryville plant to Entergy Gulf States pursuant to a long-term power purchase agreement.

The rate refund provisions variance is primarily due to provisions recorded in 2005 as a result of the March 2005 Global Settlement with the LPSC.

The reserve equalization variance is primarily due to a revision made in 2005 of reserve equalization payments among Entergy companies due to a FERC ruling regarding the inclusion of interruptible loads in reserve equalization calculations.

The volume/weather variance is primarily due to decreased usage during the unbilled sales period and decreased usage in the industrial sector of 181 GWh. The decrease in usage in the industrial sector is primarily a result of Hurricane Katrina.

 

84

The price applied to unbilled electric sales variance is due to the exclusion in 2006 of the fuel cost component in the calculation of the price applied to unbilled sales. Effective January 1, 2006, the fuel cost component is no longer included in the unbilled revenue calculation, which is in accordance with regulatory treatment. Entergy Louisiana expects that the effect of this factor will be an increase in net revenue of approximately $10 million for its annual results for 2006. See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates " herein for a discussion of the accounting for unbilled revenues.

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

Gross operating revenues decreased primarily due to:

  • a decrease of $58.4 million in fuel cost recovery revenues due to a lower fuel rates;
  • a decrease of $12.2 million in volume/weather, as discussed above; and
  • a decrease of $10.4 million in the price applied to unbilled electric sales, as discussed above.

The decrease was partially offset by:

  • an increase of $24.8 million in gross wholesale revenue due to increased sales to affiliated systems and the sale of a portion of the generation from Perryville;
  • an increase of $14.6 million in base revenues, as discussed above; and
  • an increase of $5.0 million due to lower rate refund provisions, as discussed above.

Fuel and purchased power expenses decreased primarily due to a decrease in the market prices of natural gas and purchased power, partially offset by an increase in the recovery from customers of deferred fuel costs.

Other regulatory credits decreased primarily due to the LPSC order for the interim recovery of storm costs effective March 2006. Refer to " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - State and Local Regulation " in the Form 10-K for a discussion of Entergy Louisiana's filing with the LPSC regarding storm cost recovery.

Other Income Statement Variances

Third Quarter 2006 Compared to Third Quarter 2005

Other operation and maintenance expenses increased primarily due to:

  • an increase of $8.5 million in payroll and benefits costs;
  • an increase of $6.8 million due to the expensing of plant maintenance costs in 2006 versus the capitalization in 2005 of storm restoration costs; and
  • an increase of $3.4 million in environmental reserves as a result of a reduction in the environmental reserve liability in the third quarter of 2005.

Other income decreased primarily due to:

  • the receipt of proceeds in 2005 of $4.6 million from the radwaste settlement, which is discussed in " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Central States Compact Claim" in the Form 10-K; and
  • $2.5 million of deferred capacity interest adjustments related to the formula rate plan filed with the LPSC in May 2006.

85

Nine Months Ended September 30, 2006 Compared to Nine Months Ended September 30, 2005

Other operation and maintenance expenses increased primarily due to:

The increase was partially offset by the following:

  • a decrease of $3.6 million due to a planned decrease in vegetation maintenance; and
  • a decrease of $2.3 million due to loss provisions recorded in 2005 for the bankruptcy of CashPoint, which managed a network of payment agents for the domestic utility companies.

Taxes other than income taxes decreased primarily due to decreased franchise taxes as a result of the merger-by-division that created Entergy Louisiana, LLC.

Depreciation and amortization expenses decreased primarily due to a change in the depreciation rate for Waterford 3 as approved by the LPSC effective April 2005 and revisions in 2005 of estimated depreciable lives involving certain intangible assets.

Other income increased primarily due to:

  • the write-off of $7.1 million in June 2005 of a portion of the customer care system investment and the related allowance for equity funds used during construction pursuant to an LPSC-approved settlement; and
  • an increase in the allowance for equity funds used during construction due to an increase in construction work in progress as a result of Hurricanes Katrina and Rita.

The increase was partially offset by the following:

  • the receipt of proceeds in 2005 of $4.6 million from the radwaste settlement, which is discussed in " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Central States Compact Claim " in the Form 10-K; and
  • $2.5 million of deferred capacity interest adjustments related to the formula rate plan filed with the LPSC in May 2006.

Income Taxes

The effective income tax rates for the third quarters of 2006 and 2005 were 39.1% and 44.6%, respectively. The effective income tax rates for the nine months ended September 30, 2006 and 2005 were 39.0% and 41.6%, respectively. The difference in the effective income tax rate for the third quarter of 2006 versus the federal statutory rate of 35.0% is primarily due to state income taxes and book and tax differences related to utility plant items. The difference in the effective income tax rate for the nine months ended September 30, 2006 versus the federal statutory rate of 35.0% is primarily due to 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 and the amortization of investment tax credits. The difference in the effective income tax rates for the third quarter 2005 and the nine months ended September 30, 2005 versus the federal statutory rate of 35.0% is primarily due to state income taxes, book and tax differences related to utility plant items, and a federal tax reserve estimate revision necessary to provide additional reserves for income tax audit matters.

86

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2006 and 2005 were as follows:

 

 

2006

 

2005

 

 

(In Thousands)

 

 

 

 

 

Cash and cash equivalents at beginning of period

 

$105,285 

 

$146,049 

 

 

 

 

 

Cash flow provided by (used in):

 

 

 

 

 

Operating activities

 

245,122 

 

86,149 

 

Investing activities

 

(362,824)

 

(370,975)

 

Financing activities

 

16,365 

 

141,943 

Net decrease in cash and cash equivalents

 

(101,337)

 

(142,883)

 

 

 

 

 

Cash and cash equivalents at end of period

 

$3,948 

 

$3,166 

Operating Activities

Cash flow from operations increased $159.0 million for the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005 primarily due to an increase in fuel cost recoveries and the effect that Hurricane Katrina had on September 2005 collections, partially offset by an increase of $54 million in pension contributions.

Investing Activities

Cash flow used by investing activities decreased $8.2 million for the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005 primarily due to the purchase of the Perryville plant in June 2005 for $162 million, substantially offset by an increase of $154 million in distribution construction expenditures due to Hurricanes Katrina and Rita and money pool activity.

Financing Activities

The decrease of $125.6 million in net cash provided by financing activities for the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005 is primarily due to:

  • the retirement of $25 million of long-term debt in 2006;
  • the net issuance of $33.6 million of long-term debt in 2005;
  • money pool activity; and
  • borrowings of $40 million on a credit facility in 2005, which was paid in 2006.

The decrease was partially offset by the following:

  • proceeds of $50 million from an equity contribution from its parent, Entergy Louisiana Holdings, in 2006; and
  • payment of $51.6 million of common stock dividends in 2005.

Capital Structure

Entergy Louisiana's capitalization is balanced between equity and debt, as shown in the following table. The decrease in debt to capital for Entergy Louisiana is primarily due to an increase in members' equity due to additional equity from its parent because of a revision in the estimate of the tax liabilities allocated to Entergy Louisiana Holdings in the merger-by-division that created Entergy Louisiana, LLC.

 

87

 

 

September 30,
2006

December 31,
2005

 

 

Net debt to net capital

 

45.8%

49.2%

Effect of subtracting cash from debt

 

 0.1%

2.1%

Debt to capital

 

 45.9%

51.3%

Net debt consists of debt less cash and cash equivalents. Debt consists of notes payable, capital lease obligations, and long-term debt, including the currently maturing portion. Capital consists of debt and members' equity. Net capital consists of capital less cash and cash equivalents. Entergy Louisiana uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Louisiana's financial condition.

Uses 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.

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

September 30,
2006

 

December 31,
2005

 

September 30,
2005

 

December 31,
2004

(In Thousands)

 

 

 

 

 

 

($104,952)

 

($68,677)

 

($124,936)

 

$40,549

See Note 4 to the domestic utility companies and System Energy financial statements in the Form 10-K for a description of the money pool.

In April 2006, Entergy Louisiana's $85 million credit facility expired and was not renewed. Also, Entergy Louisiana's $15 million credit facility expired in May 2006 and was not renewed.

In June 2006, Entergy Louisiana redeemed, prior to maturity, $25 million of 5.95% Series of St. Charles Parish bonds.

The Pension Protection Act of 2006

The Pension Protection Act of 2006 was signed by the President on August 17, 2006. The intent of the legislation is to require companies to fund 100% of their pension liability; and then for companies to fund, on a going-forward basis, an amount generally estimated to be the amount that the pension liability increases each year due to an additional year of service by the employees eligible for pension benefits. The legislation requires that funding shortfalls be eliminated by companies over a seven-year period, beginning in 2008.

The Pension Protection Act also extended the provisions of the Pension Funding Equity Act that would have expired in 2006 had the Pension Protection Act not been enacted, which increased the allowed discount rate used to calculate the pension funding liability. Entergy Louisiana is in the process of evaluating the effects of the new legislation, but expects that the implementation of the Pension Protection Act will not result in annual pension contributions going-forward that are materially higher than the levels required in 2005 and 2006.

88

Significant Factors and Known Trends

See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends " in the Form 10-K for a discussion of state and local rate regulation, federal regulation and proceedings, the Energy Policy Act of 2005, utility restructuring, market and credit risks, nuclear matters, environmental risks, and litigation risks.

State and Local Rate Regulation

In May 2006, Entergy Louisiana made its formula rate plan filing with the LPSC for the 2005 test year. Entergy Louisiana modified the filing in August 2006 to reflect a 9.45% return on equity which is within the allowed bandwidth. The modified filing includes an increase of $24 million for interim recovery of storm costs from Hurricanes Katrina and Rita and a $120 million rate increase to recover LPSC-approved incremental deferred and ongoing capacity costs. The filing requested recovery of approximately $50 million for the amortization of capacity deferrals over a three-year period, including carrying charges, and approximately $70 million for ongoing capacity costs. The increase was implemented, subject to refund, with the first billing cycle of September 2006. Comments were provided by the LPSC Staff, which Entergy Louisiana is currently reviewing. Entergy Louisiana subsequently updated its formula rate plan rider to reflect adjustments proposed by the LPSC Staff with which it agrees. The adjusted return on equity of 9.56% remains within the allowed bandwidth. Ongoing and deferred incremental capacity costs were reduced to $119 million. The updated formula rate plan rider was implemented, subject to refund, with the first billing cycle of October 2006.

Federal Regulation

System Agreement Proceedings

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - System Agreement Litigation , APSC Complaint at the FERC , APSC System Agreement Investigation , and MPSC System Agreement Inquiry " for updates regarding proceedings involving the System Agreement.

Independent Coordinator of Transmission (ICT)

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - Independent Coordinator of Transmission " for an update regarding Entergy's ICT proposal.

Available Flowgate Capacity (AFC) Proceeding

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - Available Flowgate Capacity Proceeding " for updates regarding the AFC proceeding at the FERC.

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 costs. Following is an update to that discussion.

89

Unbilled Revenue

As discussed in Note 7 to the domestic utility companies and System Energy financial statements, effective January 1, 2006, Entergy Louisiana reclassified the fuel component of unbilled accounts receivable to deferred fuel and will no longer include the fuel component in its unbilled revenue calculation, which is in accordance with regulatory treatment.

Recently Issued Accounting Pronouncements

FASB Interpretation No. 48, "Accounting for Uncertainty in Income Taxes" (FIN 48) was issued in July 2006 and is effective for Entergy Louisiana in the first quarter of 2007. The FASB's objective in issuing this interpretation is to increase comparability among companies in financial reporting of income taxes. FIN 48 establishes a "more-likely-than-not" recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return, but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. Entergy Louisiana does not expect that the adoption of FIN 48 will materially affect its financial position, results of operations, or cash flows.

In September 2006, FASB issued SFAS 158, "Employers' Accounting for Defined Benefit Pension and Other Postretirement Plans", an amendment of FASB Statements Nos. 87, 88, 106 and 132(R)," to be effective December 31, 2006. SFAS 158 requires employers to recognize the overfunded or underfunded status of a defined benefit postretirement plan as an asset or liability in its balance sheet with the offset recorded to other comprehensive income. Entergy Louisiana has previously disclosed its funded status in Note 10 to the domestic utility companies and System Energy financial statements in the Form 10-K. SFAS 158 also requires that changes in that funded status be recorded in other comprehensive income in the period in which the changes occur. Entergy Louisiana recovers other postretirement benefit costs on a pay as you go basis. Entergy Louisiana's analysis including the regulatory accounting requirements to support recording the majority of the effect of the adoption of this standard as a regulatory asset is not yet complete. Entergy Louisiana does not expect the implementation of this standard, however, to materially affect its financial position or results of operations.

90

ENTERGY LOUISIANA, LLC
INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2006 and 2005
(Unaudited)
 
  Three Months Ended   Nine Months Ended
    2006   2005   2006   2005
    (In Thousands)   (In Thousands)
                 
OPERATING REVENUES                
Domestic electric   $762,840    $760,916    $1,865,477    $1,889,337 
                 
OPERATING EXPENSES                
Operation and Maintenance:                
  Fuel, fuel-related expenses, and                
   gas purchased for resale   253,915    300,865    563,389    566,206 
  Purchased power   215,682    243,423    604,349    641,420 
  Nuclear refueling outage expenses   3,766    4,234    12,263    11,055 
  Other operation and maintenance   96,699    74,155    279,263    262,310 
Decommissioning   4,350    3,921    12,817    14,793 
Taxes other than income taxes   16,075    18,390    47,254    55,047 
Depreciation and amortization   48,366    45,776    137,868    141,229 
Other regulatory credits - net   (11,474)   (19,761)   (39,518)   (50,168)
TOTAL   627,379    671,003    1,617,685    1,641,892 
                 
OPERATING INCOME   135,461    89,913    247,792    247,445 
                 
OTHER INCOME                
Allowance for equity funds used during construction   2,572    1,189    11,749    5,566 
Interest and dividend income   63    7,983    9,315    16,123 
Miscellaneous - net   (782)   100    (2,200)   (6,749)
TOTAL   1,853    9,272    18,864    14,940 
                 
INTEREST AND OTHER CHARGES  
Interest on long-term debt   18,658    18,878    59,661    53,569 
Other interest - net   2,692    3,764    7,023    8,587 
Allowance for borrowed funds used during construction   (1,906)   (865)   (8,419)   (3,354)
TOTAL   19,444    21,777    58,265    58,802 
                 
INCOME BEFORE INCOME TAXES   117,870    77,408    208,391    203,583 
                 
Income taxes   46,068    34,548    81,239    84,789 
                 
NET INCOME   71,802    42,860    127,152    118,794 
                 
Preferred dividend requirements and other   1,738      5,213   
                 
EARNINGS APPLICABLE TO                
COMMON EQUITY   $70,064    $42,860    $121,939    $118,794 
                 
See Notes to Respective Financial Statements.                
                 

91

 

 

 

 

 

 

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92

 

ENTERGY LOUISIANA, LLC
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2006 and 2005
(Unaudited)
     
    2006   2005
    (In Thousands)
         
OPERATING ACTIVITIES        
Net income   $127,152    $118,794 
Adjustments to reconcile net income to net cash flow provided by operating activities:        
  Reserve for regulatory adjustments   255    (15,301)
  Other regulatory credits - net   (39,518)   (50,168)
  Depreciation, amortization, and decommissioning   150,685    156,022 
  Deferred income taxes and investment tax credits   13,329    55,050 
  Changes in working capital:        
    Receivables   49,810    (228,031)
    Accounts payable   (35,973)   294,319 
    Taxes accrued   74,499    52,406 
    Interest accrued   (2,904)   3,420 
    Deferred fuel costs   (81,410)   (87,290)
    Other working capital accounts   25,146    (41,426)
  Provision for estimated losses and reserves   4,281    154 
  Changes in other regulatory assets   3,899    (258,267)
  Other   (44,129)   86,467 
Net cash flow provided by operating activities   245,122    86,149 
         
INVESTING ACTIVITIES        
Construction expenditures   (343,938)   (216,209)
Allowance for equity funds used during construction   11,749    5,566 
Nuclear fuel purchases   (44,819)   (54,498)
Proceeds from the sale/leaseback of nuclear fuel   44,819    54,498 
Payment for purchase of plant     (162,075)
Proceeds from nuclear decommissioning trust fund sales   13,013    93,072 
Investment in nuclear decommissioning trust funds   (19,233)   (100,212)
Change in money pool receivable - net     40,549 
Other regulatory investments   (24,415)   (31,666)
Net cash flow used in investing activities   (362,824)   (370,975)
         
FINANCING ACTIVITIES        
Proceeds from the issuance of long-term debt     253,016 
Proceeds from the issuance of preferred membership interests   50,013   
Retirement of long-term debt   (25,000)   (219,374)
Change in money pool payable - net   36,275    124,936 
Changes in credit borrowing, net   (40,000)   40,000 
Dividends paid:        
  Common stock    -    (51,600)
  Preferred stock   (4,923)   (5,035)
Net cash flow provided by financing activities   16,365    141,943 
         
Net decrease in cash and cash equivalents   (101,337)   (142,883)
         
Cash and cash equivalents at beginning of period   105,285    146,049 
         
Cash and cash equivalents at end of period   $3,948    $3,166 
         
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:        
Cash paid during the period for:        
  Interest - net of amount capitalized   $66,605    $56,194 
  Income taxes   $17,230    $11,114 
         
See Notes to Respective Financial Statements.        

93

 

ENTERGY LOUISIANA, LLC
BALANCE SHEETS
ASSETS
September 30, 2006 and December 31, 2005
(Unaudited)
   
  2006   2005
  (In Thousands)
         
CURRENT ASSETS        
Cash and cash equivalents   $3,948    $105,285 
Accounts receivable:        
  Customer   160,657    176,169 
  Allowance for doubtful accounts   (2,260)   (6,141)
  Associated companies   50,951    24,453 
  Other   11,948    12,553 
  Accrued unbilled revenues   85,836    149,908 
     Total accounts receivable   307,132    356,942 
Deferred fuel costs   35,297    21,885 
Accumulated deferred income taxes     3,884 
Materials and supplies - at average cost   98,971    92,275 
Deferred nuclear refueling outage costs   2,807    15,337 
Prepayments and other   8,600    173,055 
TOTAL   456,755    768,663 
         
OTHER PROPERTY AND INVESTMENTS        
Decommissioning trust funds   199,348    187,101 
Non-utility property - at cost (less accumulated depreciation)   1,715    1,852 
Other    
TOTAL   201,067    188,957 
         
UTILITY PLANT        
Electric   6,533,596    6,233,711 
Property under capital lease   250,610    250,610 
Construction work in progress   228,291    415,475 
Nuclear fuel under capital lease   76,229    58,492 
TOTAL UTILITY PLANT   7,088,726    6,958,288 
Less - accumulated depreciation and amortization   2,848,357    2,805,944 
UTILITY PLANT - NET   4,240,369    4,152,344 
         
DEFERRED DEBITS AND OTHER ASSETS        
Regulatory assets:        
  SFAS 109 regulatory asset - net   70,041    104,893 
  Other regulatory assets   611,969    599,451 
  Deferred fuel costs   67,998   
Long-term receivables   6,302    8,222 
Other   27,570    32,523 
TOTAL   783,880    745,089 
           
TOTAL ASSETS   $5,682,071    $5,855,053 
         
See Notes to Respective Financial Statements.        
 
94
 
ENTERGY LOUISIANA, LLC
BALANCE SHEETS
LIABILITIES AND MEMBERS' EQUITY
September 30, 2006 and December 31, 2005
(Unaudited)
   
  2006   2005
  (In Thousands)
 
CURRENT LIABILITIES        
Notes payable   $-   $40,000
Accounts payable:        
  Associated companies   182,912   121,382
  Other   174,958   398,507
Customer deposits   70,563   66,705
Taxes accrued   77,641   88,548
Accumulated deferred income taxes   21,878   -
Interest accrued   25,538   28,442
Obligations under capital leases   33,463   22,753
Other   28,154   8,721
TOTAL   615,107   775,058
         
NON-CURRENT LIABILITIES        
Accumulated deferred income taxes and taxes accrued   1,868,777   2,055,083
Accumulated deferred investment tax credits   90,041   92,439
Obligations under capital leases   42,766   35,740
Other regulatory liabilities   47,662   58,129
Decommissioning   234,108   221,291
Accumulated provisions   97,446   93,165
Long-term debt   1,147,644   1,172,400
Other   95,870   146,576
TOTAL   3,624,314   3,874,823
         
Commitments and Contingencies        
         
MEMBERS' EQUITY        
Preferred membership interests without sinking fund   100,000   100,000
Members' equity   1,342,650   1,105,172
TOTAL   1,442,650   1,205,172
         
TOTAL LIABILITIES AND MEMBERS' EQUITY   $5,682,071   $5,855,053
         
See Notes to Respective Financial Statements.        

95

 

ENTERGY LOUISIANA, LLC
STATEMENTS OF MEMBERS' EQUITY
For the Three and Nine Months Ended September 30, 2006 and 2005
(Unaudited)
         
    Three Months Ended
    2006   2005
    (In Thousands)
MEMBERS' EQUITY        
Members' Equity - Beginning of period   $1,222,603   $1,080,780
         
  Add:        
    Net income   71,802   42,860
    Additional equity from parent   50,000   -
    121,802   42,860
         
  Deduct:        
    Distributions declared:        
      Common equity   -   27,100
      Preferred membership interests   1,738   -
    Other   17   -
    1,755   27,100
         
Members' Equity - End of period   $1,342,650   $1,096,540
         
         
         
    Nine Months Ended
    2006   2005
    (In Thousands)
MEMBERS' EQUITY        
Members' Equity - Beginning of period   $1,105,172   $1,029,346
         
  Add:        
    Net income   127,152   118,794
    Additional equity from parent   115,703   -
    242,855   118,794
         
  Deduct:        
    Distributions declared:        
      Common equity   -   51,600
      Preferred membership interests   5,213   -
    Other   164   -
    5,377   51,600
         
Members' Equity - End of period   $1,342,650   $1,096,540
         
         
         
See Notes to Respective Financial Statements.        
         

96

 

ENTERGY LOUISIANA, LLC
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2006 and 2005
(Unaudited)
 
                 
    Three Months Ended   Increase/    
Description   2006   2005   (Decrease)   %
    (Dollars In Millions)    
Electric Operating Revenues:                
  Residential   $286   $283   $3     1  
  Commercial   160   159   1     1  
  Industrial   219   225   (6)   (3)
  Governmental   10   10   -     -  
     Total retail   675   677   (2)   -  
  Sales for resale                
    Associated companies   50   112   (62)   (55)
    Non-associated companies   5   5   -     -  
  Other   33   (33)   66     200  
     Total   $763   $761   $2     -  
                 
Billed Electric Energy                
 Sales (GWh):                
  Residential   2,924   2,802   122     4  
  Commercial   1,697   1,605   92     6  
  Industrial   3,353   3,146   207     7  
  Governmental   112   101   11     11  
     Total retail   8,086   7,654   432     6  
  Sales for resale                
    Associated companies   665   980   (315)   (32)
    Non-associated companies   50   43   7     16  
     Total   8,801   8,677   124     1  
                 
                 
    Nine Months Ended   Increase/    
Description   2006   2005   (Decrease)   %
    (Dollars In Millions)    
Electric Operating Revenues:                
  Residential   $610   $620   ($10)   (2)
  Commercial   396   396   -     -  
  Industrial   589   612   (23)   (4)
  Governmental   30   30   -     -  
     Total retail   1,625   1,658   (33)   (2)
  Sales for resale                
    Associated companies   183   159   24     15  
    Non-associated companies   10   10   -     -  
  Other   47   62   (15)   (24)
     Total   $1,865   $1,889   ($24)   (1)
                 
Billed Electric Energy                
 Sales (GWh):                
  Residential   6,642   6,625   17     -  
  Commercial   4,325   4,252   73     2  
  Industrial   9,422   9,603   (181)   (2)
  Governmental   328   327   1     -  
     Total retail   20,717   20,807   (90)   -  
  Sales for resale                
    Associated companies   1,960   1,410   550     39  
    Non-associated companies   89   89   -     -  
     Total   22,766   22,306   460     2  
                 
                 

97

 

ENTERGY MISSISSIPPI, INC.

MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS

Hurricane Katrina

See the Form 10-K for a discussion of the effects of Hurricane Katrina, which hit Entergy Mississippi's service territory in August 2005 causing power outages and significant infrastructure damage to Entergy Mississippi's distribution and transmission systems. Entergy Mississippi currently estimates that its total restoration costs for the repair and/or replacement of its electric facilities damaged by Hurricane Katrina, and business continuity costs, and a small amount of damage caused by Hurricane Rita, will be $107 million.

As discussed in the Form 10-K, a federal hurricane aid package became law in late 2005 and early 2006 that includes funding for Community Development Block Grants (CDBG) that allows state and local leaders to fund individual recovery priorities. The law permits funding for infrastructure restoration. In March 2006, the Governor of Mississippi signed a law that established a mechanism by which the MPSC could authorize and certify an electric utility financing order and the state could issue general obligation bonds to finance the costs of repairing damage caused by Hurricane Katrina to the systems of investor-owned electric utilities.  Because of the passage of this law and the possibility of Entergy Mississippi obtaining CDBG funds for Hurricane Katrina storm restoration costs, in March 2006, the MPSC issued an order approving a Joint Stipulation between Entergy Mississippi and the Mississippi Public Utilities Staff that provided for a review of Entergy Mississippi's total storm restoration costs in an Application for an Accounting Order proceeding.  The Stipulation stated that the procedural schedule of Entergy Mississippi's December 2005 filing seeking recovery of hurricane costs through an existing Entergy Mississippi storm damage rider should be suspended until the MPSC issues a final order in the Application for an Accounting Order proceeding. 

In June 2006, the MPSC issued an order certifying Entergy Mississippi's Hurricane Katrina restoration costs incurred through March 31, 2006 of $89 million, net of estimated insurance proceeds. Two days later, Entergy Mississippi filed a request with the Mississippi Development Authority for $89 million of CDBG funding for reimbursement of its Hurricane Katrina infrastructure restoration costs. Entergy Mississippi also filed a Petition for Financing Order with the MPSC for authorization of state general obligation bond financing of $169 million for Hurricane Katrina restoration costs and future storm costs. The $169 million amount included the $89 million of Hurricane Katrina restoration costs plus $80 million to build Entergy Mississippi's storm damage reserve for the future. Entergy Mississippi's filing stated that the amount actually financed through the state bonds would be net of any CDBG funds that Entergy Mississippi received.

In October 2006, the Mississippi Development Authority approved for payment and Entergy Mississippi received $81 million in CDBG funding for Hurricane Katrina costs. The MPSC then issued a financing order authorizing the issuance of $48 million of state general obligation bonds, with $8 million for the remainder of Entergy Mississippi's certified Hurricane Katrina restoration costs and $40 million for the increase in Entergy Mississippi's storm damage reserve. $30 million of the storm reserve will be set aside in a restricted account. Entergy Mississippi expects to forward the financing order to the state bond commission, as per the March 2006 law, and expects to receive the proceeds from the state general obligation bond issuance in the first quarter of 2007.

98

Results of Operations

Net Income

Third Quarter 2006 Compared to Third Quarter 2005

Net income decreased $2.1 million primarily due to higher other operation and maintenance expense, higher taxes other than income taxes, and higher interest charges, partially offset by higher net revenue.

Nine Months Ended September 30, 2006 Compared to Nine Months Ended September 30, 2005

Net income decreased $4.0 million primarily due to higher other operation and maintenance expense, higher taxes other than income taxes, and higher interest charges, partially offset by higher net revenue.

Net Revenue

Third Quarter 2006 Compared to Third Quarter 2005

Net revenue, which is Entergy Mississippi's measure of gross margin, 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 third quarter of 2006 to the third quarter of 2005.

   

Amount

   

(In Millions)

     

2005 net revenue

 

$135.8  

Price applied to unbilled electric sales

 

6.4  

Deferral of Attala costs

 

5.4  

Volume/weather

 

5.2  

Other

 

(3.4)

2006 net revenue

 

$149.4 

The price applied to unbilled electric sales variance is primarily due to the increase in the power management rider rates applied to unbilled sales.

The deferral of Attala costs variance is primarily due to the under-recovery of Attala power plant costs that will be recovered through the power management rider. The net income effect of this cost deferral is partially offset by Attala costs in other operation and maintenance expenses, depreciation expense, and taxes other than income taxes.

The volume/weather variance is primarily due to an increase in electricity usage, including the effect of more favorable weather during the third quarter of 2006 compared to the third quarter of 2005. Billed electricity usage increased a total of 133 GWh in the service territory.

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

Gross operating revenues increased primarily due to an increase of $24.3 million in fuel cost recovery revenues due to higher fuel rates.

Fuel and purchased power expenses increased primarily due to increased recovery of fuel and purchased power costs due to an increase in fuel rates, partially offset by a decrease in the market prices of natural gas and purchased power and a decrease in demand.

99

Other regulatory credits increased primarily due to the refunding through the power management recovery rider in 2006 of over-recoveries in 2005 as a result of gains recorded on gas hedging contracts, in addition to the under-recovery of Attala costs, discussed above. There is no material effect on net income due to quarterly adjustments to the power management recovery rider.

Nine Months Ended September 30, 2006 Compared to Nine Months Ended September 30, 2005

Net revenue, which is Entergy Mississippi's measure of gross margin, 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, 2006 to the nine months ended September 30, 2005.

   

Amount

   

(In Millions)

     

2005 net revenue

 

$343.6  

Deferral of Attala costs

 

19.8  

Volume/weather

 

8.4  

Reserve Equalization

 

(4.8)

Other

 

(2.5)

2006 net revenue

 

$364.5 

The deferral of Attala costs variance is primarily due to the under-recovery of Attala power plant costs that will be recovered through the power management rider. The net income effect of this cost deferral is partially offset by Attala costs in other operation and maintenance expenses, depreciation expense, and taxes other than income taxes.

The volume/weather variance is primarily due to an increase in electricity usage, including the effect of more favorable weather during the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005. Billed electricity usage increased a total of 326 GWh in the service territory.

The reserve equalization variance is primarily due to changes in the Entergy System generation mix compared to the same period in 2005 and a revision of reserve equalization payments among Entergy companies due to a FERC ruling regarding the inclusion of interruptible loads in reserve equalization calculations.

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

Gross operating revenues increased primarily due to an increase of $263.2 million in fuel cost recovery revenues due to higher fuel rates.

Fuel and purchased power expenses increased primarily due to increased recovery of fuel and purchased power costs due to an increase in fuel rates.

Other regulatory credits increased primarily due to the refunding through the power management recovery rider in 2006 of over-recoveries in 2005 as a result of gains recorded on gas hedging contracts, in addition to the under-recovery of Attala costs, discussed above. There is no material effect on net income due to quarterly adjustments to the power management recovery rider.

100

Other Income Statement Variances

Third Quarter 2006 Compared to Third Quarter 2005

Other operation and maintenance expense increased primarily due to:

  • an increase of $3.8 million in payroll and benefits costs;
  • an increase of $3.5 million in costs associated with the purchase of the Attala plant which was in January 2006; and
  • an increase of $2.0 million in customer service costs, including an increase in customer write-offs.

Taxes other than income taxes increased primarily due to higher franchise taxes in 2006 due to higher revenues.

Interest charges increased primarily due to additional long-term debt issued to finance the Attala power plant purchase.

Nine Months Ended September 30, 2006 Compared to Nine Months Ended September 30, 2005

Other operation and maintenance expense increased primarily due to:

  • an increase of $7.9 million in costs associated with the purchase of the Attala plant which was in January 2006;
  • an increase of $4.0 million in customer service costs, including an increase in customer write-offs;
  • an increase of $4.0 million due to the reclassification of storm charges from a regulatory asset in accordance with a Joint Stipulation with the MPSC; and
  • an increase of $3.6 million in payroll and benefit costs.

The increase was partially offset by a decrease of $5.1 million in plant maintenance costs at certain fossil plants and a decrease of $3.0 million due to a planned decrease in vegetation maintenance in 2006.

Taxes other than income taxes increased primarily due to higher assessed values for ad valorem tax purposes as a result of the Attala plant purchase and higher franchise taxes in 2006 due to higher revenues.

Interest charges increased primarily due to additional long-term debt issued to finance the Attala power plant purchase.

Income Taxes

The effective income tax rates for the third quarters of 2006 and 2005 were 36.9% and 37.4%, respectively. The effective income tax rates for the nine months ended September 30, 2006 and 2005 were 34.8% and 35.8%, respectively. The difference in the effective tax rates for the third quarters of 2006 and 2005 versus the federal statutory rate of 35.0% are primarily due to state income taxes.

101

 

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2006 and 2005 were as follows:

 

 

2006

 

2005

 

 

(In Thousands)

 

 

 

 

 

Cash and cash equivalents at beginning of period

 

$4,523 

 

$80,396 

 

 

 

 

 

Cash flow provided by (used in):

 

 

 

 

 

Operating activities

 

297,417 

 

56,441 

 

Investing activities

 

(272,823)

 

(100,644)

 

Financing activities

 

8,180 

 

(25,236)

Net increase (decrease) in cash and cash equivalents

 

32,774 

 

(69,439)

 

 

 

 

 

Cash and cash equivalents at end of period

 

$37,297 

 

$10,957 

Operating Activities

Cash flow from operations increased $241.0 million for the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005 primarily due to increased collection of fuel and purchased power costs and the income tax refund in 2006, discussed below, partially offset by an increase of $15 million in pension contributions.

In the first quarter of 2006, Entergy Corporation received an income tax refund as a result of net operating loss carryback provisions contained in the Gulf Opportunity Zone Act of 2005, as discussed in Note 3 to the domestic utilities companies and System Energy financial statements in the Form 10-K. In accordance with Entergy's intercompany tax allocation agreement, in April 2006 Entergy Corporation distributed $66 million of the refund to Entergy Mississippi.

Investing Activities

Net cash used in investing activities increased $172.2 million for the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005 primarily due to the purchase of the 480 MW Attala power plant for $88 million in January 2006, increased storm-related spending, and money pool activity.

Financing Activities

Entergy Mississippi provided $8.2 million of cash for financing activities for the nine months ended September 30, 2006 compared to using $25.2 million for financing activities for the nine months ended September 30, 2005 primarily due to the issuance of $100 million of first mortgage bonds during 2006 and a decrease of $17 million in common stock dividends, partially offset by money pool activity.

102

Capital Structure

Entergy Mississippi's capitalization is balanced between equity and debt, as shown in the following table. The increase in the debt to capital percentage as of September 30, 2006 is primarily due to the issuance of $100 million of First Mortgage Bonds in January 2006.

 

 

September 30,
2006

 

December 31,
2005

 

 

 

 

 

Net debt to net capital

 

53.0%

 

52.6%

Effect of subtracting cash from debt

 

1.2%

 

0.1%

Debt to capital

 

54.2%

 

52.7%

Net debt consists of debt less cash and cash equivalents. Debt consists of notes payable, capital lease obligations, and long-term debt, including the currently maturing portion. Capital consists of debt and shareholders' equity. Net capital consists of capital less cash and cash equivalents. Entergy Mississippi uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Mississippi's financial condition.

Uses of Capital

See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources " in the Form 10-K for a discussion of Entergy Mississippi's uses of capital. Following are updates to the information presented in the Form 10-K.

See the table in the Form 10-K under " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYIS - Liquidity and Capital Resources - Uses of Capital " which sets forth the amounts of Entergy Mississippi's planned construction and other capital investments for 2006 through 2008. In January 2006, Entergy Mississippi purchased for $88 million the Attala power plant, a 480 MW natural gas-fired, combined-cycle generating facility owned by Central Mississippi Generating Company. Entergy Mississippi plans to invest approximately $20 million in facility upgrades at the Attala plant plus $3 million in other costs, bringing the total capital cost of the project to approximately $111 million. The planned construction and other capital investments line includes the majority of the estimated cost of the Attala acquisition as a 2006 capital commitment.

In November 2005, the MPSC issued an order approving the acquisition of the Attala plant. In December 2005, the MPSC issued an order approving the investment cost recovery through the power management rider and limited the recovery through the rider to a period that begins with the closing date of the purchase and ends the earlier of the date costs are incorporated into base rates or December 31, 2006.

As a consequence of the events surrounding Entergy Mississippi's ongoing efforts to recover storm restoration costs associated with Hurricane Katrina, in October 2006, the MPSC approved a revision to Entergy Mississippi's power management rider. The revision has the effect of allowing Entergy Mississippi to recover the annual ownership costs of the Attala plant until such time as there has been a resolution of Entergy Mississippi's recovery of its storm restoration costs and a general rate case can be filed.

103

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 sources of capital. Following are updates to the information presented in the Form 10-K.

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

September 30,
2006

 

December 31,
2005

 

September 30,
2005

 

December 31,
2004

(In Thousands)

 

 

 

 

 

 

 

$73,137

 

($84,066)

 

$24,015

 

$21,584

See Note 4 to the domestic utility companies and System Energy financial statements in the Form 10-K for a description of the money pool.

In May 2006, Entergy Mississippi increased its $25 million credit facility to $30 million and renewed it through May 2007. Entergy Mississippi also entered into a new $20 million credit facility through May 2007. Borrowings on these credit facilities may be secured by a security interest in Entergy Mississippi's accounts receivable. No borrowings were outstanding on either facility as of September 30, 2006.

In January 2006, Entergy Mississippi issued $100 million of 5.92% Series of First Mortgage Bonds due February 2016. Entergy Mississippi used the proceeds to purchase the Attala power plant and to repay short-term indebtedness.

The Pension Protection Act of 2006

The Pension Protection Act of 2006 was signed by the President on August 17, 2006. The intent of the legislation is to require companies to fund 100% of their pension liability; and then for companies to fund, on a going-forward basis, an amount generally estimated to be the amount that the pension liability increases each year due to an additional year of service by the employees eligible for pension benefits. The legislation requires that funding shortfalls be eliminated by companies over a seven-year period, beginning in 2008.

The Pension Protection Act also extended the provisions of the Pension Funding Equity Act that would have expired in 2006 had the Pension Protection Act not been enacted, which increased the allowed discount rate used to calculate the pension funding liability. Entergy Mississippi is in the process of evaluating the effects of the new legislation, but expects that the implementation of the Pension Protection Act will not result in annual pension contributions going-forward that are materially higher than the levels required in 2005 and 2006.

Significant Factors and Known Trends

See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends " in the Form 10-K for a discussion of, state and local rate regulation, federal regulation and proceedings and the Energy Policy Act of 2005, and market and credit risks. The following are updates to the information provided in the Form 10-K.

State and Local Rate Regulation

In March 2006, Entergy Mississippi made its annual scheduled formula rate plan filing with the MPSC.  The filing was amended by an April 2006 filing.  The amended filing showed that an increase of $3.1 million in electric revenues is warranted.  The MPSC approved a settlement providing for a $1.8 million rate increase, which was implemented in August 2006.

104

Federal Regulation

System Agreement Proceedings

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - System Agreement Litigation , APSC Complaint at the FERC , APSC System Agreement Investigation , and MPSC System Agreement Inquiry " for updates regarding proceedings involving the System Agreement.

Independent Coordinator of Transmission (ICT)

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - Independent Coordinator of Transmission " for an update regarding Entergy's ICT proposal.

Available Flowgate Capacity (AFC) Proceeding

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - Available Flowgate Capacity Proceeding " for updates regarding the AFC proceeding at the FERC.

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 pension and other retirement costs.

Recently Issued Accounting Pronouncements

FASB Interpretation No. 48, "Accounting for Uncertainty in Income Taxes" (FIN 48) was issued in July 2006 and is effective for Entergy Mississippi in the first quarter of 2007. The FASB's objective in issuing this interpretation is to increase comparability among companies in financial reporting of income taxes. FIN 48 establishes a "more-likely-than-not" recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return, but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. Entergy Mississippi does not expect that the adoption of FIN 48 will materially affect its financial position, results of operations, or cash flows.

In September 2006, FASB issued SFAS 158, "Employers' Accounting for Defined Benefit Pension and Other Postretirement Plans", an amendment of FASB Statements Nos. 87, 88, 106 and 132(R)," to be effective December 31, 2006. SFAS 158 requires employers to recognize the overfunded or underfunded status of a defined benefit postretirement plan as an asset or liability in its balance sheet with the offset recorded to other comprehensive income. Entergy Mississippi has previously disclosed its funded status in Note 10 to the domestic utility companies and System Energy financial statements in the Form 10-K. SFAS 158 also requires that changes in that funded status be recorded in other comprehensive income in the period in which the changes occur. Entergy Mississippi is generally allowed to recover pension and other postretirement benefit costs each period based upon costs calculated under SFAS 87 and SFAS 106. Entergy Mississippi's analysis including the regulatory accounting requirements to support recording the majority of the effect of the adoption of this standard as a regulatory asset is not yet complete. Entergy Mississippi does not expect the implementation of this standard, however, to materially affect its financial position or results of operations.

105

ENTERGY MISSISSIPPI, INC.
INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2006 and 2005
(Unaudited)
     
    Three Months Ended   Nine Months Ended
    2006   2005   2006   2005
    (In Thousands)   (In Thousands)
                 
OPERATING REVENUES                
Domestic electric   $429,460    $406,765    $1,190,543    $946,255 
                 
OPERATING EXPENSES                
Operation and Maintenance:                
  Fuel, fuel-related expenses, and                
   gas purchased for resale   169,458    49,886    532,616    123,177 
  Purchased power   117,316    199,029    357,076    459,313 
  Other operation and maintenance   53,475     39,497     144,487     128,228  
Taxes other than income taxes   17,080    15,254    49,303    43,920 
Depreciation and amortization   19,698    18,089    55,768    54,008 
Other regulatory charges (credits) - net   (6,717)   22,095    (63,625)   20,129 
TOTAL   370,310    343,850    1,075,625    828,775 
                 
OPERATING INCOME   59,150    62,915    114,918    117,480 
                 
OTHER INCOME                
Allowance for equity funds used during construction    747    106    2,861    2,167 
Interest and dividend income   1,979    947    2,934    2,275 
Miscellaneous - net   (289)   (324)   (1,321)   (1,015)
TOTAL   2,437    729    4,474    3,427 
                 
INTEREST AND OTHER CHARGES      
Interest on long-term debt   11,474    9,881    34,081    29,554 
Other interest - net   1,194    962    4,063    2,407 
Allowance for borrowed funds used during construction   (499)   (443)   (1,896)   (1,787)
TOTAL   12,169    10,400    36,248    30,174 
                 
INCOME BEFORE INCOME TAXES   49,418    53,244    83,144    90,733 
                 
Income taxes   18,232     19,917     28,914     32,465  
                 
NET INCOME   31,186    33,327    54,230    58,268 
                 
Preferred dividend requirements and other   707    909    2,121    2,609 
                 
EARNINGS APPLICABLE TO                
COMMON STOCK   $30,479    $32,418    $52,109    $55,659 
                 
See Notes to Respective Financial Statements.                
                 

106

 

ENTERGY MISSISSIPPI, INC.
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2006 and 2005
(Unaudited)
     
    2006   2005
    (In Thousands)
         
OPERATING ACTIVITIES        
Net income   $54,230    $58,268 
Adjustments to reconcile net income to net cash flow provided by operating activities:        
  Other regulatory charges (credits) - net   (63,625)   20,129 
  Depreciation and amortization   55,768    54,008 
  Deferred income taxes and investment tax credits   (59,855)   28,915 
  Changes in working capital:        
    Receivables   (18,458)   (98,392)
    Fuel inventory   (3,033)   793 
    Accounts payable   (39,966)   170,044 
    Taxes accrued   146,098    (6,793)
    Interest accrued   2,185    4,494 
    Deferred fuel costs   222,177    (100,646)
    Other working capital accounts   17,470    (3,530)
  Provision for estimated losses and reserves   (7)   (3,221)
  Changes in other regulatory assets   (39,436)   (67,012)
  Other   23,869    (616)
Net cash flow provided by operating activities   297,417    56,441 
         
INVESTING ACTIVITIES        
Construction expenditures   (112,847)   (100,380)
Payment for purchase of plant   (88,199)  
Allowance for equity funds used during construction   2,861    2,167 
Changes in other temporary investments - net   (1,501)  
Change in money pool receivable - net   (73,137)   (2,431)
Net cash flow used in investing activities   (272,823)   (100,644)
         
FINANCING ACTIVITIES        
Proceeds from the issuance of:        
Proceeds from the issuance of long-term debt   99,167    (55)
Proceeds from the issuance of common stock     226 
Proceeds from the issuance of preferred stock     29,229 
Redemption of preferred stock     (30,269)
Change in money pool payable - net   (84,066)  
Dividends paid:        
  Common stock   (4,800)   (21,900)
  Preferred stock   (2,121)   (2,467)
Net cash flow provided by (used in) financing activities   8,180    (25,236)
         
Net increase (decrease) in cash and cash equivalents   32,774    (69,439)
         
Cash and cash equivalents at beginning of period   4,523    80,396 
         
Cash and cash equivalents at end of period   $37,297    $10,957 
         
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:        
Cash paid/(received) during the period for:        
  Interest - net of amount capitalized   $34,367    $16,186 
  Income taxes   ($65,803)   $4,446 
         
See Notes to Respective Financial Statements        

107

 

ENTERGY MISSISSIPPI, INC.
BALANCE SHEETS
ASSETS
September 30, 2006 and December 31, 2005
(Unaudited)
     
  2006   2005
  (In Thousands)
         
CURRENT ASSETS        
Cash and cash equivalents:        
  Cash   $4,324    $4,523 
  Temporary cash investments - cost,        
   which approximates market   32,973   
     Total cash and cash equivalents   37,297    4,523 
Accounts receivable:        
  Customer   110,076    102,202 
  Allowance for doubtful accounts   (1,030)   (1,826)
  Associated companies   80,473    5,415 
  Other   8,711    9,254 
  Accrued unbilled revenues   42,122    33,712 
     Total accounts receivable   240,352    148,757 
Deferred fuel costs     113,956 
Accumulated deferred income taxes   3,003   
Fuel inventory - at average cost   6,120    3,087 
Materials and supplies - at average cost   27,939    21,521 
Prepayments and other   5,077    62,759 
TOTAL   319,788    354,603 
         
OTHER PROPERTY AND INVESTMENTS        
Investment in affiliates - at equity   5,531    5,531 
Non-utility property - at cost (less accumulated depreciation)   6,096    6,199 
TOTAL   11,627    11,730 
         
UTILITY PLANT        
Electric   2,673,995    2,473,035 
Property under capital lease   30    50 
Construction work in progress   79,434    119,354 
TOTAL UTILITY PLANT   2,753,459    2,592,439 
Less - accumulated depreciation and amortization   922,280    886,687 
UTILITY PLANT - NET   1,831,179    1,705,752 
         
DEFERRED DEBITS AND OTHER ASSETS        
Regulatory assets:        
  SFAS 109 regulatory asset - net   20,266    17,073 
  Other regulatory assets   210,379    186,197 
Long-term receivable   2,443    3,270 
Other   30,670    32,418 
TOTAL   263,758    238,958 
         
TOTAL ASSETS   $2,426,352    $2,311,043 
         
See Notes to Respective Financial Statements.        
 
108
 
ENTERGY MISSISSIPPI, INC.
BALANCE SHEETS
LIABILITIES AND SHAREHOLDERS' EQUITY
September 30, 2006 and December 31, 2005
(Unaudited)
     
  2006   2005
  (In Thousands)
 
CURRENT LIABILITIES        
Accounts payable:        
  Associated companies   $ 50,949     $ 158,579  
  Other   39,856    83,306 
Customer deposits   49,385    44,025 
Taxes accrued   39,775    33,121 
Accumulated deferred income taxes     13,233 
Interest accrued   15,836    13,651 
Deferred fuel costs   108,221   
Obligations under capital leases   15    40 
Other   15,936    2,739 
TOTAL   319,973    348,694 
         
NON-CURRENT LIABILITIES        
Accumulated deferred income taxes and taxes accrued   540,401    491,857 
Accumulated deferred investment tax credits   11,375    12,358 
Obligations under capital leases     11 
Other regulatory liabilities     34,368 
Retirement cost liabilities   4,193    4,016 
Accumulated provisions   9,429    9,436 
Long-term debt   795,168    695,146 
Other   74,943    91,588 
TOTAL   1,435,509    1,338,780 
         
Commitments and Contingencies        
         
SHAREHOLDERS' EQUITY        
Preferred stock without sinking fund   50,381    50,381 
Common stock, no par value, authorized 15,000,000        
 shares; issued and outstanding 8,666,357 shares in 2006 and 2005   199,326    199,326 
Capital stock expense and other   (690)   (682)
Retained earnings   421,853    374,544 
TOTAL   670,870    623,569 
         
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY   $2,426,352    $2,311,043 
         
See Notes to Respective Financial Statements.        

109

 

ENTERGY MISSISSIPPI, INC.
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2006 and 2005
(Unaudited)
 
                 
    Three Months Ended   Increase/    
Description   2006   2005   (Decrease)   %
    (Dollars In Millions)    
Electric Operating Revenues:                
  Residential   $ 189   $ 171   $ 18    11 
  Commercial   133   122   11   
  Industrial   56   52    
  Governmental   12   11    
     Total retail   390   356   34    10 
  Sales for resale                
     Associated companies   13   30   (17)   (57)
     Non-associated companies   12   12    
  Other   15   9     67 
     Total   $ 430   $ 407   $ 23   
                 
Billed Electric Energy                
 Sales (GWh):                
  Residential   1,905   1,822   83   
  Commercial   1,443   1,397   46   
  Industrial   768   772   (4)   (1)
  Governmental   125   117    
     Total retail   4,241   4,108   133   
  Sales for resale                
    Associated companies   143   269   (126)   (47)
    Non-associated companies   161   171   (10)   (6)
     Total   4,545   4,548   (3)  
                 
                 
    Nine Months Ended   Increase/    
Description   2006   2005   (Decrease)   %
    (Dollars In Millions)    
Electric Operating Revenues:                
  Residential   $ 471   $ 366   $ 105    29 
  Commercial   391   298   93    31 
  Industrial   188   143   45    31 
  Governmental   37   29     28 
     Total retail   1,087   836   251    30 
  Sales for resale                
    Associated companies   36   47   (11)   (23)
    Non-associated companies   31   29    
  Other   36   34    
     Total   $ 1,190   $ 946   $ 244    26 
                 
Billed Electric Energy                
 Sales (GWh):                
  Residential   4,235   4,078   157   
  Commercial   3,611   3,475   136   
  Industrial   2,189   2,171   18   
  Governmental   318   303   15   
     Total retail   10,353   10,027   326   
  Sales for resale                
    Associated companies   397   390    
    Non-associated companies   342   348   (6)   (2)
     Total   11,092   10,765   327   
                 

110

 

ENTERGY NEW ORLEANS, INC. (Debtor-in-possession)

MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS

 

Hurricane Katrina

See the Form 10-K for a discussion of the effects of Hurricane Katrina, which in August 2005 caused catastrophic damage to Entergy New Orleans' service territory, including the effect of extensive flooding that resulted from levee breaks in and around the New Orleans area. Following is an update to the discussion in the Form 10-K.

As discussed in the Form 10-K, a federal hurricane aid package became law that includes funding for Community Development Block Grants (CDBG) that allows state and local leaders to fund individual recovery priorities. The law permits funding for infrastructure restoration. The U.S. Department of Housing and Urban Development has allocated approximately $10.4 billion for Louisiana, $5.5 billion for Mississippi, and $0.5 billion for Texas. The states, in turn, will administer the grants. In March 2006, Entergy New Orleans provided a justification statement to state and local officials. The statement included all the estimated costs of Hurricane Katrina damage, as well as a lost customer base component intended to help offset the need for storm-related rate increases. The statement included justification for a request for $718 million in CDBG funding. In September 2006, Entergy New Orleans presented a revised CDBG request to the Louisiana Recovery Authority's Infrastructure Committee. The updated request of $592 million takes into account the sale of output of Entergy New Orleans's share of Grand Gulf nuclear power into the wholesale market for a period of time longer than originally anticipated, lower operation and maintenance expenses, and the cessation of interest payments on long-term debt for an agreed-upon period of one year. In October 2006, the Louisiana Recovery Authority Board endorsed a resolution proposing to allocate $200 million in CDBG funds to Entergy New Orleans to defray gas and electric utility system repair costs in an effort to provide rate relief for Entergy New Orleans customers. The proposal will now be developed as an action plan amendment and published for public comment. Once public input is reviewed and considered, the final plan will come before the Louisiana Recovery Authority Board, the Governor, and the Louisiana Legislature for approval before submission of the plan to the U. S. Department of Housing and Urban Development for its approval. The City Council will certify the amount of Entergy New Orleans' repair costs before they are submitted for funding.

In the first quarter 2006, Entergy New Orleans reduced its accrued accounts payable for storm restoration costs by $97.4 million, with corresponding reductions of $88.7 million in construction work in progress and $8.7 million in regulatory assets, based on a reassessment of the nature and timing of expected restoration and rebuilding costs and the obligations associated with restoring service. Although Entergy New Orleans reduced its accrual for restoration spending by these amounts, it continues to expect to incur the related costs over time and Entergy New Orleans still expects its storm restoration and business continuity costs to total approximately $275 million. As discussed further in the Form 10-K, in addition to the estimated storm restoration costs, it will be necessary for Entergy New Orleans to rebuild the gas distribution system in New Orleans due to the massive salt water intrusion into the system caused by the flooding. Entergy New Orleans currently expects the cost of the gas system rebuilding to be $355 million, with the project beginning in 2008 and extending for many years thereafter.

As discussed more fully in the Form 10-K, Entergy New Orleans is pursuing insurance recovery for its covered losses caused by Hurricane Katrina. Entergy New Orleans has received $7.2 million thus far on its insurance claims. Entergy New Orleans currently expects to receive payment for the majority of its estimated insurance recovery related to Hurricane Katrina through 2009.

See " State and Local Rate Regulation " below for a discussion of rate filings made by Entergy New Orleans directed towards recovery of its storm losses and restoration costs.

111

 

Bankruptcy Proceedings

See Note 14 to the domestic utility companies and System Energy financial statements in the Form 10-K for a discussion of the Entergy New Orleans bankruptcy proceeding. Following are updates to that discussion.

As discussed in the Form 10-K, the bankruptcy court issued its order in December 2005 giving final approval for the $200 million debtor-in-possession credit facility, and the indenture trustee for Entergy New Orleans' first mortgage bonds appealed the order. On March 29, 2006 the bankruptcy court approved a settlement among Entergy New Orleans, Entergy Corporation, and the indenture trustee, and the indenture trustee dismissed its appeal.

On October 23, 2006 Entergy New Orleans filed a plan of reorganization and a disclosure statement with the bankruptcy court. Objections to the disclosure statement must be filed by November 29, 2006, and a hearing regarding its adequacy is scheduled for December 7, 2006. The period within which Entergy New Orleans has the exclusive right to solicit acceptance of its plan of reorganization will expire on December 22, 2006, unless it is further extended by the bankruptcy court.

The bankruptcy court also extended the time within which Entergy New Orleans has an exclusive right to file a plan of reorganization until November 15, 2006. Financial Guaranty Insurance Company (FGIC), the insurer of two series totaling $75 million of Entergy New Orleans' first mortgage bonds, filed a motion to terminate the exclusive period within which Entergy New Orleans has an exclusive right to file and solicit acceptances of a plan of reorganization. FGIC asks the court to allow itself or other stakeholders the right to file an alternative and competing plan of reorganization and to solicit acceptances for such a proposed plan. FGIC's motion to terminate exclusivity is set for hearing on November 15, 2006.

The plan of reorganization reflects Entergy New Orleans' continuing effort to work with federal, state, and local authorities to resolve the bankruptcy in a manner that allows Entergy New Orleans' customers to be served by a financially viable entity as required by law. The plan of reorganization also provides full compensation to Entergy New Orleans' creditors whose claims are allowed by the bankruptcy court. Conditions precedent proposed in the plan of reorganization, as currently filed, before it can become effective include:

  • A final confirmation order from the bankruptcy court approving the plan of reorganization;
  • Implementation of a City Council resolution that is satisfactory to Entergy New Orleans regarding its formula rate plan gas and electric filings and its proposed storm cost recovery and storm reserve riders;
  • Receipt by Entergy New Orleans of insurance proceeds of at least $250 million or assurance of such receipt, or alternatively, assurance that regulatory mechanisms will be put in place to cover any shortfall in insurance proceeds;
  • Receipt by Entergy New Orleans of $200 million in CDBG funding and assurance that at a minimum an additional $200 million in CDBG funding will be available for future gas system rebuild or assurance from the City Council that an appropriate rate mechanism is in place to allow Entergy New Orleans to recover the costs thereof;
  • No material adverse change shall have occurred from and after the confirmation date of the plan of reorganization; and
  • Entergy New Orleans receives a final order from the FERC authorizing issuance of short-term debt securities under credit agreements, the Entergy System money pool, and unilateral arrangements with Entergy Corporation.

In addition, key factors that will continue to influence the timing and outcome of Entergy New Orleans' recovery efforts include the level of economic recovery of New Orleans and the number of customers that return to New Orleans, including the timing of their return. Entergy New Orleans currently estimates that approximately 85,000 electric customers and 65,000 gas customers have returned and are taking service. Prior to Hurricane Katrina, Entergy New Orleans had approximately 190,000 electric customers and 145,000 gas customers.

112

The bankruptcy judge set a date of April 19, 2006 by which creditors with prepetition claims against Entergy New Orleans, with certain exceptions, had to file their proofs of claim in the bankruptcy case. Approximately 550 claims, including amending claims, have been filed thus far in Entergy New Orleans' bankruptcy proceeding. Entergy New Orleans is currently analyzing the accuracy and validity of the claims filed, and has begun seeking withdrawal or modification of claims or objecting to claims with which it disagrees. Several of the filed claims have been withdrawn. Entergy New Orleans currently estimates that the pre-petition claims that will be allowed in the bankruptcy case will approximate the pre-petition liabilities that have been classified as liabilities subject to compromise in Entergy New Orleans' Balance Sheet as of September 30, 2006. The plan of reorganization proposes to pay the third party pre-petition accounts payable in full in cash, to issue two-year notes in satisfaction of the affiliate pre-petition accounts payable, and proposes that the first mortgage bonds will remain outstanding with their current maturity dates and interest terms. The plan of reorganization proposes that Entergy New Orleans' preferred stock will also remain outstanding on its current dividend terms.

Municipalization is one potential outcome of Entergy New Orleans' recovery effort that may be pursued by a stakeholder or stakeholders, either in the reorganization process or after Entergy New Orleans exits from bankruptcy. In June 2006, the Louisiana Legislature passed a law that establishes a governance structure for a public power authority, if municipalization of Entergy New Orleans' utility business is pursued. Entergy New Orleans' settlement of its formula rate plan and storm cost and reserve rider proceedings, discussed further below, provides that Entergy New Orleans will work with the City Council to seek an exception to the Stafford Act that will afford Stafford Act protections to Entergy New Orleans if another catastrophic event affects Entergy New Orleans. The Stafford Act provides for restoration funding from the federal government for municipal utilities, but does not allow such funding for investor-owned utilities like Entergy New Orleans.

Results of Operations

Net Income

Third Quarter 2006 Compared to Third Quarter 2005

Net income increased slightly primarily due to higher net revenue, lower taxes other than income taxes, and lower interest charges, substantially offset by higher operation and maintenance expense.

Nine Months Ended September 30, 2006 Compared to Nine Months Ended September 30, 2005

Net income increased $3.3 million primarily due to lower operation and maintenance expense, lower interest charges, lower taxes other than income taxes, and higher other income, partially offset by lower net revenue.

Net Revenue

Third Quarter 2006 Compared to Third Quarter 2005

Net revenue, which is Entergy New Orleans' measure of gross margin, 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 changes in net revenue comparing the third quarter of 2006 to the third quarter of 2005.

   

Amount

   

(In Millions)

     

2005 net revenue

 

$55.7 

Fuel revenue

 

23.9 

Volume/weather

 

(10.4)

Price applied to unbilled electric sales

 

(7.3)

Net wholesale revenue

 

(2.9)

Other

 

(1.0)

2006 net revenue

 

$58.0 

113

The fuel revenue variance is due to the inclusion of Grand Gulf costs in fuel recoveries effective July 1, 2006. In June 2006, the City Council approved the recovery of all Grand Gulf costs through Entergy New Orleans' fuel adjustment clause, without a corresponding change in base rates (a significant portion of Grand Gulf costs was previously recovered through base rates).  In June 2006, the City Council also approved the return of Grand Gulf output to serve Entergy New Orleans' retail load effective July 1, 2006, as discussed further below in the nine months ended discussion.

The volume/weather variance is due to a decrease in electricity usage in the service territory caused by customer losses following Hurricane Katrina. Billed retail electricity usage decreased a total of 206 GWh compared to the third quarter of 2005, a decline of 15%. Entergy New Orleans currently estimates that approximately 85,000 electric customers and 65,000 gas customers have returned and are taking service. Prior to Hurricane Katrina, Entergy New Orleans had approximately 190,000 electric customers and 145,000 gas customers.

The price applied to unbilled electric sales variance is primarily due to a decrease in the fuel cost component of the price applied to unbilled sales. The decrease in the fuel cost component is due to a decrease in the average cost of generation due to a change in the generation mix from natural gas to solid fuel resources. See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates " in the Form 10-K and Note 1 to the domestic utility companies and System Energy financial statements in the Form 10-K for further discussion of the accounting for unbilled revenues.

The net wholesale revenue variance is due to a decrease in sales volume as a result of the discontinuance of sales of Grand Gulf output to third parties. In June 2006, the City Council approved the return of Grand Gulf output to serve Entergy New Orleans' retail load effective July 1, 2006.

Nine Months Ended September 30, 2006 Compared to Nine Months Ended September 30, 2005

Net revenue, which is Entergy New Orleans' measure of gross margin, 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, 2006 to the nine months ended September 30, 2005.

   

Amount

   

(In Millions)

     

2005 net revenue

 

$175.6 

Volume/weather

 

(63.6)

Price applied to unbilled electric sales

 

(10.5)

Net gas revenue

 

(6.4)

Net wholesale revenue

 

38.3 

Fuel revenue

 

23.9 

Other

 

(7.7)

2006 net revenue

 

$149.6 

The volume/weather variance is due to a decrease in electricity usage in the service territory caused by customer losses following Hurricane Katrina. Billed retail electricity usage decreased a total of 1,283 GWh compared to the nine months ended September 30, 2005, a decline of 32%. Entergy New Orleans currently estimates that approximately 85,000 electric customers and 65,000 gas customers have returned and are taking service. Prior to Hurricane Katrina, Entergy New Orleans had approximately 190,000 electric customers and 145,000 gas customers.

The price applied to unbilled electric sales variance is primarily due to a decrease in the fuel cost component of the price applied to unbilled sales. The decrease in the fuel cost component is due to a decrease in the average cost of generation due to a change in the generation mix from natural gas to solid fuel resources. See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates " in the

114

 

 Form 10-K and Note 1 to the domestic utility companies and System Energy financial statements in the Form 10-K for further discussion of the accounting for unbilled revenues.

The net gas revenue variance is due to a decrease in gas usage in the service territory caused by customer losses following Hurricane Katrina, partially offset by a revised estimate of deferred fuel costs.

The net wholesale revenue variance is due to an increase in energy available for sales for resale due to the decrease in retail usage caused by customer losses following Hurricane Katrina. The increased revenue includes the sales into the wholesale market of Entergy New Orleans' share of the output of Grand Gulf, pursuant to City Council approval of measures proposed by Entergy New Orleans to address the reduction in Entergy New Orleans' retail customer demand caused by Hurricane Katrina and provide revenue support for the costs of Entergy New Orleans' share of Grand Gulf. In June 2006, the City Council approved the return of Grand Gulf output to serve Entergy New Orleans' retail load effective July 1, 2006.

The fuel revenue variance is due to the inclusion of Grand Gulf costs in fuel recoveries effective July 1, 2006. In June 2006, the City Council approved the recovery of all Grand Gulf costs through Entergy New Orleans' fuel adjustment clause, without a corresponding change in base rates (a significant portion of Grand Gulf costs was previously recovered through base rates).

Other Income Statement Variances

Third Quarter 2006 Compared to Third Quarter 2005

Taxes other than income taxes decreased primarily due to lower franchise taxes in 2006 due to lower revenues.

Interest and other charges decreased primarily due to the cessation of interest accruals on the first mortgage bonds as a result of the bankruptcy filing, partially offset by interest accrued on the DIP credit facility. On September 23, 2006, when the interest moratorium agreed to by the bondholders expired, Entergy New Orleans resumed interest accrual on the First Mortgage Bonds.

Nine Months Ended September 30, 2006 Compared to Nine Months Ended September 30, 2005

Other operation and maintenance expenses decreased primarily due to shifts in costs from normal operations and maintenance work to storm restoration work as a result of Hurricane Katrina.

Taxes other than income taxes decreased primarily due to lower franchise taxes in 2006 due to lower revenues.

Interest and other charges decreased primarily due to the cessation of interest accruals on the first mortgage bonds as a result of the bankruptcy filing, partially offset by interest accrued on the DIP credit facility. On September 23, 2006, when the interest moratorium agreed to by the bondholders expired, Entergy New Orleans resumed interest accrual on the First Mortgage Bonds.

Income Taxes

The effective income tax rates for the third quarters of 2006 and 2005 were 40.9% and 41.5%, respectively. The effective income tax rates for the nine months ended September 30, 2006 and 2005 were 39.1% and 40.7%, respectively. The differences in the effective income tax rates for the periods presented versus the federal statutory rate of 35.0% are primarily due to state income taxes and book and tax differences related to utility plant items, partially offset by book and tax differences related to the allowance for equity funds used during construction.

115

Preferred Dividends

No preferred dividends were declared during the first quarter of 2006. Due to its bankruptcy, Entergy New Orleans did not pay the preferred stock dividends due October 1, 2005; January 1, 2006; or April 1, 2006. 

As discussed further in the Form 10-K, if dividends with respect to the 4.75% preferred stock were not paid for four quarters, the holders of these shares would have the right to elect a majority of the Entergy New Orleans board of directors.  Entergy New Orleans filed a motion in the bankruptcy court seeking authority to recommence paying dividends to the holders of the 4.75% preferred shares. After a hearing on the motion on May 3, 2006, the court granted Entergy New Orleans the authority to pay dividends to the holders of the 4.75% preferred shares, beginning with the dividend due on July 1, 2006, and thereafter, unless objections are filed by creditors forty-five days in advance of a dividend payment date. If any objections are filed, the matter would be heard by the bankruptcy court. Entergy New Orleans declared and paid the dividend due on July 1 and October 1, 2006, and intends to declare and pay the dividends on the 4.75% preferred shares each quarter pending resolution of its plan of reorganization.

Liquidity and Capital Resources

Debtor-in-Possession Credit Facility

See the Form 10-K for a discussion of the Entergy New Orleans debtor-in-possession (DIP) credit facility. Following is an update to that discussion.

As discussed in the Form 10-K, the bankruptcy court issued its order in December 2005 giving final approval for the $200 million DIP credit facility, and the indenture trustee for Entergy New Orleans' first mortgage bonds appealed the order. On March 29, 2006 the bankruptcy court approved a settlement among Entergy New Orleans, Entergy Corporation, and the indenture trustee, and the indenture trustee dismissed its appeal. As of September 30, 2006, Entergy New Orleans had approximately $32 million of outstanding borrowings under the DIP credit facility. Management currently expects the bankruptcy court-authorized funding level to be sufficient to fund Entergy New Orleans' expected level of operations.

As discussed in the Form 10-K, borrowings under the DIP credit facility would be due in full, and the agreement would terminate, at the earliest of several times or events, which included August 23, 2006. Entergy Corporation and Entergy New Orleans agreed to an amendment to the DIP credit agreement that extends the August 23, 2006 maturity date to August 23, 2007.

Cash Flow

Cash flows for the nine months ended September 30, 2006 and 2005 were as follows:

 

 

2006

 

2005

 

 

(In Thousands)

 

 

 

 

 

Cash and cash equivalents at beginning of period

 

$48,056 

 

$7,954 

 

 

 

 

 

Cash flow provided by (used in):

 

 

 

 

 

Operating activities

 

96,197 

 

(33,652)

 

Investing activities

 

(57,952)

 

(31,641)

 

Financing activities

 

(73,344)

 

104,025 

Net increase (decrease) in cash and cash equivalents

 

(35,099)

 

38,732 

 

 

 

 

 

Cash and cash equivalents at end of period

 

$12,957 

 

$46,686 

116

Operating Activities

Entergy New Orleans provided $96.2 million of cash in operating activities for 2006 compared to using $33.7 million of cash for 2005 primarily due to:

  • a tax refund of $59.1 million in 2006 compared to a tax refund of $18 million in 2005;
  • the effect that Hurricane Katrina had on collections in 2005;
  • the increased collection of deferred fuel costs; and
  • pension fund contributions of $14 million made in 2005.

These increases were partially offset by increased payments to vendors.

In the first quarter of 2006, Entergy Corporation received an income tax refund as a result of net operating loss carryback provisions contained in the Gulf Opportunity Zone Act of 2005, as discussed in Note 3 to the domestic utilities companies and System Energy financial statements in the Form 10-K. In accordance with Entergy's intercompany tax allocation agreement, in April 2006, Entergy Corporation distributed $71 million of the refund to Entergy New Orleans. Entergy New Orleans used the income tax refund to repay a portion of the borrowings outstanding under the DIP credit facility.

Investing Activities

Net cash used in investing activities increased $26.3 million for the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005 primarily due to capital expenditure activity related to Hurricane Katrina.

Financing Activities

Entergy New Orleans used $73.3 million in financing activities for the nine months ended September 30, 2006 compared to providing $104 million for the nine months ended September 30, 2005 primarily due to:

  • $60 million of borrowings under the DIP credit facility in 2005 which provided cash and a net repayment of $58.2 million in 2006;
  • $15 million of borrowings under the 364-day credit facility in 2005 which provided cash and the repayment by setoff of the $15 million in 2006; and
  • money pool activity in 2005.

The increases above were partially offset by a decrease in dividends paid of $5.3 million.

Capital Structure

Entergy New Orleans' capitalization is shown in the following table.

 

 

September 30,
2006

 

December 31,
2005

 

 

 

 

 

Debt to capital

 

57.3%

 

66.4%

Debt consists of notes payable and long-term debt, including the currently maturing portion. Capital consists of debt and shareholders' equity.

117

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' uses and sources of capital. The following are updates to the Form 10-K.

Entergy New Orleans' receivables from or (payables to) the money pool were as follows:

September 30,
2006

 

December 31,
2005

 

September 30,
2005

 

December 31,
2004

(In Thousands)

 

 

 

 

 

 

 

($37,166)

 

($37,166)

 

($37,166)

 

$1,413

See Note 4 to the domestic utility companies and System Energy financial statements in the Form 10-K for a description of the money pool. Entergy New Orleans remains a participant in the money pool, but Entergy New Orleans has not made, and does not expect to make, any additional borrowings from the money pool while it is in bankruptcy proceedings. The money pool borrowings reflected on Entergy New Orleans' balance sheet as of September 30, 2006 are classified as a pre-petition obligation subject to compromise.

In addition, Entergy New Orleans had a 364-day credit facility in the amount of $15 million which expired in May 2006. As authorized by the bankruptcy judge, in July 2006, Entergy New Orleans set off $15 million of its cash held by the lender against the outstanding debt on the credit facility.

The Pension Protection Act of 2006

The Pension Protection Act of 2006 was signed by the President on August 17, 2006. The intent of the legislation is to require companies to fund 100% of their pension liability; and then for companies to fund, on a going-forward basis, an amount generally estimated to be the amount that the pension liability increases each year due to an additional year of service by the employees eligible for pension benefits. The legislation requires that funding shortfalls be eliminated by companies over a seven-year period, beginning in 2008.

The Pension Protection Act also extended the provisions of the Pension Funding Equity Act that would have expired in 2006 had the Pension Protection Act not been enacted, which increased the allowed discount rate used to calculate the pension funding liability. Entergy New Orleans is in the process of evaluating the effects of the new legislation, but expects that the implementation of the Pension Protection Act will not result in annual pension contributions going-forward that are materially higher than the levels that would have been required prior to passage of the Pension Protection Act.

Significant Factors and Known Trends

See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends " in the Form 10-K for a discussion of state and local rate regulation, federal regulation and proceedings, the Energy Policy Act of 2005, market and credit risks, environmental risks, and litigation risks. Following are updates to the discussion in the Form 10-K.

State and Local Rate Regulation

In June 2006, Entergy New Orleans made its annual formula rate plan filings with the City Council.  The filings presented various alternatives to reflect the effect of Entergy New Orleans' lost customers and decreased revenue. Entergy New Orleans' recommended alternative adjusts for lost customers and assumes that the City Council's June 2006 decision to allow recovery of all Grand Gulf costs through the fuel adjustment clause stays in place during the rate-effective period (a significant portion of Grand Gulf costs was previously recovered through base rates).

118

At the same time as it made its formula rate plan filings, Entergy New Orleans also filed with the City Council a request to implement two storm-related riders. With the first rider, Entergy New Orleans sought to recover the electric and gas restoration costs that it had actually spent through March 31, 2006. Entergy New Orleans also proposed semiannual filings to update the rider for additional restoration spending and also to consider the receipt of CDBG funds or insurance proceeds that it may receive. With the second rider, Entergy New Orleans sought to establish a storm reserve to provide for the risk of another storm.

In October 2006, the City Council approved a settlement agreement that resolves Entergy New Orleans' rate and storm-related rider filings by providing for phased-in rate increases, while taking into account with respect to storm restoration costs the anticipated receipt of CDBG funding as recommended by the Louisiana Recovery Authority. The settlement provides for a 0% increase in electric base rates through December 2007, with a $3.9 million increase implemented in January 2008. Recovery of all Grand Gulf costs through the fuel adjustment clause will continue. Gas base rates will increase by $4.75 million in November 2006, an additional $1.5 million in March 2007, and an additional $4.75 million in November 2007. The settlement calls for Entergy New Orleans to file a base rate case by July 31, 2008. Any storm costs in excess of CDBG funding and insurance proceeds will be addressed in that base rate case. A storm cost recovery rider is authorized but initially set at $0 because of the anticipated receipt of CDBG funding. The settlement also authorizes a $75 million storm reserve for damage from future storms, which will be created over a ten-year period through a storm reserve rider beginning in March 2007. These storm reserve funds will be held in a restricted escrow account.

Federal Regulation

System Agreement Proceedings

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - System Agreement Litigation , APSC Complaint at the FERC , APSC System Agreement Investigation , and MPSC System Agreement Inquiry " for updates regarding proceedings involving the System Agreement.

Independent Coordinator of Transmission (ICT)

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - Independent Coordinator of Transmission " for an update regarding Entergy's ICT proposal.

Available Flowgate Capacity (AFC) Proceeding

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - Available Flowgate Capacity Proceeding " for updates regarding the AFC proceeding at the FERC.

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' accounting for unbilled revenue and pension and other retirement costs.

119

Recently Issued Accounting Pronouncements

FASB Interpretation No. 48, "Accounting for Uncertainty in Income Taxes" (FIN 48) was issued in July 2006 and is effective for Entergy New Orleans in the first quarter of 2007. The FASB's objective in issuing this interpretation is to increase comparability among companies in financial reporting of income taxes. FIN 48 establishes a "more-likely-than-not" recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return, but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. Entergy New Orleans does not expect that the adoption of FIN 48 will materially affect its financial position, results of operations, or cash flows.

In September 2006, FASB issued SFAS 158, "Employers' Accounting for Defined Benefit Pension and Other Postretirement Plans", an amendment of FASB Statements Nos. 87, 88, 106 and 132(R)," to be effective December 31, 2006. SFAS 158 requires employers to recognize the overfunded or underfunded status of a defined benefit postretirement plan as an asset or liability in its balance sheet with the offset recorded to other comprehensive income. Entergy New Orleans has previously disclosed its funded status in Note 10 to the domestic utility companies and System Energy financial statements in the Form 10-K. SFAS 158 also requires that changes in that funded status be recorded in other comprehensive income in the period in which the changes occur. Entergy New Orleans is generally allowed to recover pension and other postretirement benefit costs each period based upon costs calculated under SFAS 87 and SFAS 106. Entergy New Orleans' analysis including the regulatory accounting requirements to support recording the majority of the effect of the adoption of this standard as a regulatory asset is not yet complete. Entergy New Orleans does not expect the implementation of this standard, however, to materially affect its financial position or results of operations.

120

ENTERGY NEW ORLEANS, INC.
(DEBTOR-IN-POSSESSION)
INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2006 and 2005
(Unaudited)
                 
  Three Months Ended   Nine Months Ended
    2006   2005   2006   2005
    (In Thousands)   (In Thousands)
                 
OPERATING REVENUES                
Domestic electric   $146,105    $169,823    $363,181    $459,794 
Natural gas   15,538    19,770    70,678    110,993 
TOTAL   161,643    189,593    433,859    570,787 
                 
OPERATING EXPENSES                
Operation and Maintenance:                
  Fuel, fuel-related expenses, and                
   gas purchased for resale   56,098    54,460    107,199    190,399 
  Purchased power   46,504    79,915    173,952    202,699 
  Other operation and maintenance   22,193     21,592     54,135     72,582  
Taxes other than income taxes   9,164    11,497    25,853    32,869 
Depreciation and amortization   8,775    8,634    24,747    25,779 
Reorganization items   4,853      6,793   
Other regulatory charges (credits) - net   1,040    (455)   3,120    2,054 
TOTAL   148,627    175,643    395,799    526,382 
                 
OPERATING INCOME   13,016    13,950    38,060    44,405 
                 
OTHER INCOME                
Allowance for equity funds used during construction   540    286    2,528    814 
Interest and dividend income   768    631    2,357    1,157 
Miscellaneous - net   (123)   (208)   (255)   (585)
TOTAL   1,185    709    4,630    1,386 
                 
INTEREST AND OTHER CHARGES          
Interest on long-term debt   455    3,237    824    10,241 
Other interest - net   1,603    678    4,741    1,546 
Allowance for borrowed funds used during construction   (428)   (217)   (2,034)   (634)
TOTAL   1,630    3,698    3,531    11,153 
                 
INCOME BEFORE INCOME TAXES   12,571    10,961    39,159    34,638 
                 
Income taxes   5,141     4,544     15,312     14,111  
                  
NET INCOME   7,430    6,417    23,847    20,527 
                 
Preferred dividend requirements and other   93      185    482 
                 
EARNINGS APPLICABLE TO                
COMMON STOCK   $7,337    $6,417    $23,662    $20,045 
                 
See Notes to Respective Financial Statements.                
                 

 

121

 

 

 

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122

 

ENTERGY NEW ORLEANS, INC.
(DEBTOR-IN-POSSESSION)
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2006 and 2005
(Unaudited)
     
    2006   2005
    (In Thousands)
OPERATING ACTIVITIES        
Net income   $23,847    $20,527 
Adjustments to reconcile net income to net cash flow provided by (used in) operating activities:        
  Other regulatory charges - net   3,120    2,054 
  Depreciation and amortization   24,747    25,779 
  Deferred income taxes and investment tax credits   (3,154)   14,216 
  Changes in working capital:        
    Receivables   11,147    (46,993)
    Fuel inventory   4,494    (2,816)
    Accounts payable   (6,045)   102,935 
    Taxes accrued   73,000    16,426 
    Interest accrued   1,098    (2,197)
    Deferred fuel costs   2,202    (38,698)
    Other working capital accounts   (4,245)   (10,428)
  Provision for estimated losses and reserves   98    (1,467)
  Changes in pension liability   4,393    (10,694)
  Changes in other regulatory assets   (45,320)   (113,109)
  Other   6,815    10,813 
Net cash flow provided by (used in) operating activities   96,197    (33,652)
         
INVESTING ACTIVITIES        
Construction expenditures   (60,480)   (34,095)
Allowance for equity funds used during construction   2,528    814 
Change in money pool receivable - net     1,640 
Net cash flow used in investing activities   (57,952)   (31,641)
         
FINANCING ACTIVITIES        
Borrowings on DIP credit facility     60,000 
Repayment on DIP credit facility   (58,159)  
Proceeds from the issuance of long-term debt     29,783 
Retirement of long-term debt     (30,065)
Changes in money pool payable - net     35,331 
Changes in short-term borrowing   (15,000)   15,000 
Dividends paid:        
  Common stock     (5,300)
  Preferred stock   (185)   (724)
Net cash flow provided by (used in) financing activities   (73,344)   104,025 
         
Net increase (decrease) in cash and cash equivalents   (35,099)   38,732 
         
Cash and cash equivalents at beginning of period   48,056    7,954 
         
Cash and cash equivalents at end of period   $12,957    $46,686 
         
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:        
Cash paid/(received) during the period for:        
  Interest - net of amount capitalized   $3,914    $13,404 
  Income taxes   ($59,062)   ($18,000)
         
See Notes to Respective Financial Statements.        

123

 

 

ENTERGY NEW ORLEANS, INC.
(DEBTOR-IN-POSSESSION)
BALANCE SHEETS
ASSETS
September 30, 2006 and December 31, 2005
(Unaudited)
   
  2006   2005
  (In Thousands)
         
CURRENT ASSETS        
Cash and cash equivalents   $12,957     $48,056  
Accounts receivable:        
  Customer   61,631     82,052  
  Allowance for doubtful accounts   (10,781)   (25,422)
  Associated companies   5,065     17,895  
  Other   6,933     6,530  
  Accrued unbilled revenues   30,758     23,698  
     Total accounts receivable   93,606     104,753  
Deferred fuel costs   28,391     30,593  
Fuel inventory - at average cost   3,554     8,048  
Materials and supplies - at average cost   6,905     8,961  
Prepayments and other   6,880     61,581  
TOTAL   152,293     261,992  
         
OTHER PROPERTY AND INVESTMENTS        
Investment in affiliates - at equity   3,259     3,259  
Non-utility property at cost (less accumulated depreciation)   1,107     1,107  
TOTAL   4,366     4,366  
         
UTILITY PLANT        
Electric   745,271     691,045  
Natural gas   193,642     189,207  
Construction work in progress   53,759     202,353  
TOTAL UTILITY PLANT   992,672     1,082,605  
Less - accumulated depreciation and amortization   437,717     428,053  
UTILITY PLANT - NET   554,955     654,552  
         
DEFERRED DEBITS AND OTHER ASSETS        
Regulatory assets:        
  Other regulatory assets   175,389     166,133  
Long term receivables   1,022     1,812  
Other   21,883     31,266  
TOTAL   198,294     199,211  
          
TOTAL ASSETS   $909,908    $1,120,121 
         
See Notes to Respective Financial Statements.        
 
124
 
ENTERGY NEW ORLEANS, INC.
(DEBTOR-IN-POSSESSION)
BALANCE SHEETS
LIABILITIES AND SHAREHOLDERS' EQUITY
September 30, 2006 and December 31, 2005
(Unaudited)
   
  2006   2005
  (In Thousands)
 
CURRENT LIABILITIES        
DIP credit facility   $31,841   $90,000
Notes payable   -   15,000
Accounts payable:        
  Associated companies   42,254   55,923
  Other   44,809   228,496
Customer deposits   13,137   16,930
Taxes accrued   2,781   -
Accumulated deferred income taxes   5,915   1,898
Interest accrued   2,022   1,195
Other   4,304   2,018
TOTAL CURRENT LIABILITIES NOT SUBJECT TO COMPROMISE   147,063   411,460
         
NON-CURRENT LIABILITIES        
Accumulated deferred income taxes and taxes accrued   123,750   125,653
Accumulated deferred investment tax credits   3,253   3,570
SFAS 109 regulatory liability - net   60,009   52,229
Other regulatory liabilities   -   591
Retirement cost liability   2,547   2,421
Accumulated provisions   2,185   2,119
Pension liability   40,087   35,694
Other   5,378   5,730
TOTAL NON-CURRENT LIABILITIES NOT SUBJECT TO COMPROMISE   237,209   228,007
         
LIABILITIES SUBJECT TO COMPROMISE   332,264   310,944
         
TOTAL LIABILITIES   716,536   950,411
         
Commitments and Contingencies        
         
SHAREHOLDERS' EQUITY        
Preferred stock without sinking fund   19,780   19,780
Common stock, $4 par value, authorized 10,000,000        
 shares; issued and outstanding 8,435,900 shares in 2006        
 and 2005   33,744   33,744
Paid-in capital   36,294   36,294
Retained earnings   103,554   79,892
TOTAL   193,372   169,710
         
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY   $909,908   $1,120,121
         
See Notes to Respective Financial Statements.        

125

 

ENTERGY NEW ORLEANS, INC.
(DEBTOR-IN-POSSESSION)
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2006 and 2005
(Unaudited)
 
                 
    Three Months Ended   Increase/    
Description   2006   2005   (Decrease)   %
   

(Dollars In Millions)

       
Electric Operating Revenues:                
  Residential   $41   $56   $ (15)   (27)
  Commercial   51   43     19 
  Industrial   14   12     17 
  Governmental   16   18   (2)   (11)
     Total retail   122   129   (7)   (5)
  Sales for resale                
    Associated companies   19   26   (7)   (27)
    Non-associated companies   0   3   (3)   (100)
  Other   5   12   (7)   (58)
     Total   $146   $170   $ (24)   (14)
                 
Billed Electric Energy                
 Sales (GWh):                
  Residential   349   538   (189)   (35)
  Commercial   501   475   26   
  Industrial   162   156    
  Governmental   166   215   (49)   (23)
     Total retail   1,178   1,384   (206)   (15)
  Sales for resale                
    Associated companies   205   468   (263)   (56)
    Non-associated companies   2   43   (41)   (95)
     Total   1,385   1,895   (510)   (27)
                 
                 
    Nine Months Ended   Increase/    
Description   2006   2005   (Decrease)   %
   

  (Dollars In Millions)

       
Electric Operating Revenues:                
  Residential   $80   $123   ($43)   (35)
  Commercial   123   117    
  Industrial   33   28     18 
  Governmental   40   47   (7)   (15)
     Total retail   276   315   (39)   (12)
  Sales for resale                
    Associated companies   30   107   (77)   (72)
    Non-associated companies   45   4   41    1,025 
  Other   12   34   (22)   (65)
     Total   $363   $460   ($97)   (21)
                 
Billed Electric Energy                
 Sales (GWh):                
  Residential   693   1,384   (691)   (50)
  Commercial   1,263   1,546   (283)   (18)
  Industrial   405   463   (58)   (13)
  Governmental   433   684   (251)   (37)
     Total retail   2,794   4,077   (1,283)   (31)
  Sales for resale                
    Associated companies   331   1,474   (1,143)   (78)
    Non-associated companies   778   54   724    1,341 
     Total   3,903   5,605   (1,702)   (30)
                 
                 
                 

126

 

SYSTEM ENERGY RESOURCES, INC.

MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

System Energy's principal asset consists of a 90% ownership and 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. Net income remained relatively unchanged for the third quarter of 2006 compared to the third quarter of 2005. Net income increased by $8.0 million for the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005 primarily due to an increase in rate base in 2006 resulting in higher operating income combined with higher interest income earned on money pool investments.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2006 and 2005 were as follows:

 

 

2006

 

2005

 

 

(In Thousands)

 

 

 

 

 

Cash and cash equivalents at beginning of period

 

$75,704 

 

$216,355 

 

 

 

 

 

Cash flow provided by (used in):

 

 

 

 

 

Operating activities

 

14,387 

 

188,312 

 

Investing activities

 

91,895 

 

(215,743)

 

Financing activities

 

(129,889)

 

(108,790)

Net decrease in cash and cash equivalents

 

(23,607)

 

(136,221)

 

 

 

 

 

Cash and cash equivalents at end of period

 

$52,097 

 

$80,134 

Operating Activities

The decrease of $173.9 million in net cash provided by operating activities for the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005 was primarily due to an increase of $183.6 million in income tax payments.

Investing Activities

Investing activities provided $91.9 million in cash flow for the nine months ended September 30, 2006 compared to using $215.7 million in cash flow for the nine months ended September 30, 2005 primarily due to money pool activity. Partially offsetting the increase in cash provided was an increase in construction expenditures primarily resulting from capital spending on dry fuel storage.

 

127

 

Financing Activities

The increase of $21.1 million in net cash used in financing activities for the nine months ended September 30, 2006 compared to the nine months ended September 30, 2005 was primarily due to an increase of $26.9 million in common stock dividends paid, partially offset by a decrease of $5.8 million in the January 2006 principal payment made on the Grand Gulf sale-leaseback compared to the January 2005 principal payment.

Capital Structure

System Energy's capitalization is balanced between equity and debt, as shown in the following table.

 

 

September 30,
2006

 

December 31,
2005

 

 

 

 

 

Net debt to net capital

 

48.9%

 

49.0%

Effect of subtracting cash from debt

 

1.5%

 

2.1%

Debt to capital

 

50.4%

 

51.1%

Net debt consists of debt less cash and cash equivalents. Debt consists of notes payable, capital lease obligations, and long-term debt, including the currently maturing portion. Capital consists of debt and common shareholder's equity. Net capital consists of capital less cash and cash equivalents. System Energy uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating System Energy's financial condition.

Uses 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. The following is an update to the Form 10-K.

System Energy's receivables from the money pool were as follows:

September 30,
2006

 

December 31,
2005

 

September 30,
2005

 

December 31,
2004

(In Thousands)

 

 

 

 

 

 

 

$147,349

 

$277,287

 

$244,323

 

$61,592

See Note 4 to the domestic utility companies and System Energy financial statements in the Form 10-K for a description of the money pool.

The Pension Protection Act of 2006

The Pension Protection Act of 2006 was signed by the President on August 17, 2006. The intent of the legislation is to require companies to fund 100% of their pension liability; and then for companies to fund, on a going-forward basis, an amount generally estimated to be the amount that the pension liability increases each year due to an additional year of service by the employees eligible for pension benefits. The legislation requires that funding shortfalls be eliminated by companies over a seven-year period, beginning in 2008.

The Pension Protection Act also extended the provisions of the Pension Funding Equity Act that would have expired in 2006 had the Pension Protection Act not been enacted, which increased the allowed discount rate used to calculate the pension funding liability. System Energy is in the process of evaluating the effects of the new legislation, but expects that the implementation of the Pension Protection Act will not result in annual pension contributions going-forward that are materially higher than the levels required in 2005 and 2006.

128

Significant Factors and Known Trends

See " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends " in the Form 10-K for a discussion of market risks, nuclear matters, litigation risks, and 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 pension and other retirement benefits.

Recently Issued Accounting Pronouncements

FASB Interpretation No. 48, "Accounting for Uncertainty in Income Taxes" (FIN 48) was issued in July 2006 and is effective for System Energy in the first quarter of 2007. The FASB's objective in issuing this interpretation is to increase comparability among companies in financial reporting of income taxes. FIN 48 establishes a "more-likely-than-not" recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return, but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. System Energy does not expect that the adoption of FIN 48 will materially affect its financial position, results of operations, or cash flows.

In September 2006, FASB issued SFAS 158, "Employers' Accounting for Defined Benefit Pension and Other Postretirement Plans", an amendment of FASB Statements Nos. 87, 88, 106 and 132(R)," to be effective December 31, 2006. SFAS 158 requires employers to recognize the overfunded or underfunded status of a defined benefit postretirement plan as an asset or liability in its balance sheet with the offset recorded to other comprehensive income. System Energy has previously disclosed its funded status in Note 10 to the domestic utility companies and System Energy financial statements in the Form 10-K. SFAS 158 also requires that changes in that funded status be recorded in other comprehensive income in the period in which the changes occur. System Energy is generally allowed to recover pension and other postretirement benefit costs each period based upon costs calculated under SFAS 87 and SFAS 106. System Energy's analysis including the regulatory accounting requirements to support recording the majority of the effect of the adoption of this standard as a regulatory asset is not yet complete. System Energy does not expect the implementation of this standard, however, to materially affect its financial position or results of operations.

 

129

SYSTEM ENERGY RESOURCES, INC.
INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2006 and 2005
(Unaudited)
 
  Three Months Ended   Nine Months Ended
    2006   2005   2006   2005
    (In Thousands)   (In Thousands)
                 
OPERATING REVENUES                
Domestic electric   $146,577    $140,583    $407,407    $391,737 
                 
OPERATING EXPENSES                
Operation and Maintenance:                
  Fuel, fuel-related expenses, and                
   gas purchased for resale   11,400    8,753    32,781    28,611 
  Nuclear refueling outage expenses   4,548    3,059    12,083    9,078 
  Other operation and maintenance   29,535     28,235     79,350     78,717  
Decommissioning   6,032    6,354    17,776    18,722 
Taxes other than income taxes   5,938    6,685    17,944    19,056 
Depreciation and amortization   33,561    33,563    83,049    84,265 
Other regulatory credits - net   (3,073)   (3,100)   (8,819)   (11,611)
TOTAL   87,941    83,549    234,164    226,838 
                 
OPERATING INCOME   58,636    57,034    173,243    164,899 
                 
OTHER INCOME                
Allowance for equity funds used during construction   462    419    1,920    1,046 
Interest and dividend income   3,533    5,402    13,433    11,919 
Miscellaneous - net   (98)   (78)   (296)   (299)
TOTAL   3,897    5,743    15,057    12,666 
                 
INTEREST AND OTHER CHARGES          
Interest on long-term debt   17,144    16,951    41,673    42,619 
Other interest - net   22      76    15 
Allowance for borrowed funds used during construction   (146)   (132)   (605)   (331)
TOTAL   17,020    16,826    41,144    42,303 
                 
INCOME BEFORE INCOME TAXES   45,513    45,951    147,156    135,262 
                 
Income taxes   18,816     19,031     60,103     56,185  
                 
NET INCOME   $26,697    $26,920    $87,053    $79,077 
                 
See Notes to Respective Financial Statements.                

130

 

SYSTEM ENERGY RESOURCES, INC.
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2006 and 2005
(Unaudited)
     
    2006   2005
    (In Thousands)
         
OPERATING ACTIVITIES        
Net income   $87,053    $79,077 
Adjustments to reconcile net income to net cash flow provided by operating activities:        
  Other regulatory credits - net   (8,819)   (11,611)
  Depreciation, amortization, and decommissioning   100,825    102,987 
  Deferred income taxes and investment tax credits   88,518    (15,023)
  Changes in working capital:        
    Receivables   (378)   (2,264)
    Accounts payable   4,232    890 
    Taxes accrued   (250,687)   36,484 
    Interest accrued   (15,414)   (13,762)
    Other working capital accounts   3,027    (4,190)
  Provision for estimated losses and reserves   10    22 
  Changes in other regulatory assets   (1,607)   (810)
  Other   7,627    16,512 
Net cash flow provided by operating activities   14,387    188,312 
         
INVESTING ACTIVITIES        
Construction expenditures   (20,994)   (16,712)
Allowance for equity funds used during construction   1,920    1,046 
Nuclear fuel purchases   (370)   (48,262)
Proceeds from sale/leaseback of nuclear fuel   370    48,262 
Proceeds from nuclear decommissioning trust fund sales   59,342    71,233 
Investment in nuclear decommissioning trust funds   (78,311)   (88,579)
Changes in money pool receivable - net   129,938    (182,731)
Net cash flow provided by (used in) investing activities   91,895    (215,743)
         
FINANCING ACTIVITIES        
Retirement of long-term debt   (22,989)   (28,790)
Dividends paid:        
  Common stock   (106,900)   (80,000)
Net cash flow used in financing activities   (129,889)   (108,790)
         
Net decrease in cash and cash equivalents   (23,607)   (136,221)
         
Cash and cash equivalents at beginning of period   75,704    216,355 
         
Cash and cash equivalents at end of period   $52,097    $80,134 
         
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:        
Cash paid during the period for:        
  I nterest - net of amount capitalized   $52,804    $52,042 
  Income taxes   $216,134    $32,522 
         
See Notes to Respective Financial Statements.        
         

131

 

SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
ASSETS
September 30, 2006 and December 31, 2005
(Unaudited)
             
    2006   2005
  (In Thousands)
             
CURRENT ASSETS            
Cash and cash equivalents:            
  Cash       $384   $204
  Temporary cash investments - at cost,            
   which approximates market       51,713   75,500
     Total cash and cash equivalents       52,097   75,704
Accounts receivable:            
  Associated companies       198,551   327,454
  Other       2,628   3,285
     Total accounts receivable       201,179   330,739
Materials and supplies - at average cost       59,317   55,183
Deferred nuclear refueling outage costs       9,618   17,853
Prepayments and other       2,773   1,878
TOTAL       324,984   481,357
             
OTHER PROPERTY AND INVESTMENTS        
Decommissioning trust funds       264,284   236,003
             
UTILITY PLANT        
Electric       3,251,075   3,212,596
Property under capital lease       467,005   467,005
Construction work in progress       27,733   47,178
Nuclear fuel under capital lease       63,624   87,500
TOTAL UTILITY PLANT       3,809,437   3,814,279
Less - accumulated depreciation and amortization       1,971,099   1,889,886
UTILITY PLANT - NET       1,838,338   1,924,393
             
DEFERRED DEBITS AND OTHER ASSETS        
Regulatory assets:            
  SFAS 109 regulatory asset - net       92,534   92,883
  Other regulatory assets       293,281   292,968
Other       16,394   18,435
TOTAL       402,209   404,286
             
TOTAL ASSETS       $2,829,815   $3,046,039
             
See Notes to Respective Financial Statements.            
 
132
 
SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
LIABILITIES AND SHAREHOLDER'S EQUITY
September 30, 2006 and December 31, 2005
(Unaudited)
             
    2006   2005
  (In Thousands)
 
CURRENT LIABILITIES        
Currently maturing long-term debt       $23,335   $22,989
Accounts payable:            
  Associated companies       2,858   -
  Other       24,144   22,770
Taxes accrued       10,018   228,168
Accumulated deferred income taxes       3,508   6,678
Interest accrued       29,695   45,109
Obligations under capital leases       30,236   27,716
Other       1,632   1,811
TOTAL       125,426   355,241
             
NON-CURRENT LIABILITIES        
Accumulated deferred income taxes and taxes accrued       323,454   267,913
Accumulated deferred investment tax credits       69,529   72,136
Obligations under capital leases       33,389   63,307
Other regulatory liabilities       247,302   224,997
Decommissioning       336,703   318,927
Accumulated provisions       2,409   2,399
Long-term debt       799,893   819,642
Other       17,929   27,849
TOTAL       1,830,608   1,797,170
             
Commitments and Contingencies            
             
SHAREHOLDER'S EQUITY        
Common stock, no par value, authorized 1,000,000 shares;            
 issued and outstanding 789,350 shares in 2006 and 2005       789,350   789,350
Retained earnings       84,431   104,278
TOTAL       873,781   893,628
             
TOTAL LIABILITIES AND SHAREHOLDER'S EQUITY       $2,829,815   $3,046,039
             
See Notes to Respective Financial Statements.            

133

 

ENTERGY ARKANSAS, ENTERGY GULF STATES, ENTERGY LOUISIANA, ENTERGY MISSISSIPPI, ENTERGY NEW ORLEANS (DEBTOR-IN-POSSESSION), AND SYSTEM ENERGY

NOTES TO RESPECTIVE FINANCIAL STATEMENTS
(Unaudited)

NOTE 1. COMMITMENTS AND CONTINGENCIES

Entergy New Orleans Bankruptcy (Entergy New Orleans)

See Note 6 to the domestic utility companies and System Energy financial statements for information on the Entergy New Orleans bankruptcy proceeding.

Nuclear Insurance (Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, and System Energy)

See Note 8 to the domestic utility companies and System Energy financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy Arkansas', Entergy Gulf States', Entergy Louisiana's, and System Energy's nuclear power plants.

Non-Nuclear Property Insurance (Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans)

See Note 8 to the domestic utility companies and System Energy financial statements in the Form 10-K for information on Entergy's non-nuclear property insurance program. Beginning in June 2006, the aggregation limit for all parties insured by Oil Insurance Limited for any one occurrence was reduced to $500 million. Most of Entergy's non-nuclear excess property insurance coverage includes a $75 million drop-down feature in the event of an OIL aggregation loss to which an Entergy loss contributes.

Nuclear Decommissioning and Other Asset Retirement Costs (Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, and System Energy)

See Note 8 to the domestic utility companies and System Energy financial statements in the Form 10-K for information on nuclear decommissioning and other retirement costs.

CashPoint Bankruptcy (Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans)

See Note 8 to the domestic utility companies and System Energy financial statements in the Form 10-K for information regarding the bankruptcy of CashPoint, which managed a network of payment agents for the domestic utility companies.

City Franchise Ordinances (Entergy New Orleans)

Entergy New Orleans provides electric and gas service in the City of New Orleans pursuant to franchise ordinances. These ordinances contain a continuing option for the City of New Orleans to purchase Entergy New Orleans' electric and gas utility properties.

Employment Litigation (Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy are defendants in numerous lawsuits filed by former employees asserting that they were wrongfully terminated and/or discriminated against on the basis of age, race, sex, or other protected characteristics. The defendant companies deny any liability to the plaintiffs.

134

Asbestos and Hazardous Material Litigation (Entergy Gulf States, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans)

See Note 8 to the domestic utility companies and System Energy financial statements in the Form 10-K for information regarding asbestos and hazardous material litigation at Entergy Gulf States, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans.

NOTE 2. RATE AND REGULATORY MATTERS

Storm Costs Recovery Filings with Retail Regulators

On July 31, 2006, Entergy Louisiana and Entergy Gulf States filed a supplemental and amending storm cost recovery application with the LPSC, in which Entergy Louisiana and Entergy Gulf States requested that the LPSC (1) review Entergy Louisiana's and Entergy Gulf States' testimony and exhibits relating to the costs associated with Hurricanes Katrina and Rita, and declare that those verified, actual storm-related costs through May 31, 2006 are $466.8 million for Entergy Louisiana and $200.3 million for Entergy Gulf States in the Louisiana jurisdiction and that those costs were prudently incurred; (2) declare that the annual revenue requirements associated with the recovery of those costs, including carrying costs, based on a ten-year levelized rate are $54.4 million for Entergy Louisiana and $26.2 million for Entergy Gulf States; (3) authorize Entergy Louisiana and Entergy Gulf States to recover the costs through Storm Cost Recovery Riders (SCRRs) proposed by Entergy Louisiana and Entergy Gulf States; (4) declare that the storm costs incurred subsequent to May 31, 2006 are to be filed by Entergy Louisiana and Entergy Gulf States with the LPSC on an annual basis in connection with their annual formula rate plan (FRP) filings, and that the SCRRs be adjusted annually to reflect such costs and any insurance proceeds or CDBG funds actually received, with the adjusted amounts to be collected through the SCRRs to take effect contemporaneous with the effective date of rate changes under the FRP; (5) declare that the storm-related costs incurred by Entergy Louisiana and Entergy Gulf States meet the conditions set forth in the FRP for exclusion from the sharing provisions in those FRPs and authorize the permanent recovery of storm costs outside of the FRPs adopted by the LPSC for Entergy Louisiana and Entergy Gulf States; and (6) authorize the funding of a storm reserve through securitization sufficient to fund a storm cost reserve of $132 million for Entergy Louisiana and $81 million for Entergy Gulf States. Hearings are scheduled for March 2007. Entergy Gulf States and Entergy Louisiana also intend to pursue securitization options for the storm cost recovery as well, which is authorized by a law signed by the Governor of Louisiana in May 2006.

In July 2006, Entergy Gulf States filed an application with the PUCT with respect to the $393.2 million of Hurricane Rita reconstruction costs incurred in its Texas retail jurisdiction through March 31, 2006. The filing asks the PUCT to determine that $393.2 million is the amount of reasonable and necessary hurricane reconstruction costs eligible for securitization and recovery, approve the recovery of carrying costs, and approve the manner in which Entergy Gulf States allocates those costs among its Texas retail customer classes.  If approved, Entergy Gulf States' application will ultimately affect all its retail customers in Texas. Entergy Gulf States' filing does not request recovery of costs through a specific rider on customer bills or through any other means at this time. This is the first of two filings authorized by a law passed earlier this year in a special session of the Texas Legislature. A hearing before the PUCT on the filing was scheduled for November 1-3, 2006, but at the commencement of the hearing all of the parties in attendance announced that they had reached a unanimous agreement in principle to settle the issues in the proceeding. The parties are developing the documentation to formalize the settlement. The parties intend to submit the settlement documents to the PUCT prior to Thanksgiving 2006 so that the PUCT can approve them by early December 2006. A second filing will request securitization and recovery of the costs eligible for securitization through retail rates and tariffs. Entergy Gulf States expects to make the second filing following the conclusion of the reconstruction cost case.

In March 2006, the Governor of Mississippi signed a law that established a mechanism by which the MPSC could authorize and certify an electric utility financing order and the state could issue general obligation bonds to finance the costs of repairing damage caused by Hurricane Katrina to the systems of investor-owned electric utilities.  Because of the passage of this law and the possibility of Entergy Mississippi obtaining CDBG funds for Hurricane Katrina storm restoration costs, in March 2006, the MPSC issued an order approving a Joint Stipulation between Entergy Mississippi

 

135

 

and the Mississippi Public Utilities Staff that provided for a review of Entergy Mississippi's total storm restoration costs in an Application for an Accounting Order proceeding.  The Stipulation stated that the procedural schedule of Entergy Mississippi's December 2005 filing seeking recovery of hurricane costs through an existing Entergy Mississippi storm damage rider should be suspended until the MPSC issues a final order in the Application for an Accounting Order proceeding. 

In June 2006, the MPSC issued an order certifying Entergy Mississippi's Hurricane Katrina restoration costs incurred through March 31, 2006 of $89 million, net of estimated insurance proceeds. Two days later, Entergy Mississippi filed a request with the Mississippi Development Authority for $89 million of CDBG funding for reimbursement of its Hurricane Katrina infrastructure restoration costs. Entergy Mississippi also filed a Petition for Financing Order with the MPSC for authorization of state general obligation bond financing of $169 million for Hurricane Katrina restoration costs and future storm costs. The $169 million amount included the $89 million of Hurricane Katrina restoration costs plus $80 million to build Entergy Mississippi's storm damage reserve for the future. Entergy Mississippi's filing stated that the amount actually financed through the state bonds would be net of any CDBG funds that Entergy Mississippi received.

In October 2006, the Mississippi Development Authority approved for payment and Entergy Mississippi received $81 million in CDBG funding for Hurricane Katrina costs. The MPSC then issued a financing order authorizing the issuance of $48 million of state general obligation bonds, with $8 million for the remainder of Entergy Mississippi's certified Hurricane Katrina restoration costs and $40 million for the increase in Entergy Mississippi's storm damage reserve. $30 million of the storm reserve will be set aside in a restricted account. Entergy Mississippi expects to forward the financing order to the state bond commission, as per the March 2006 law, and expects to receive the proceeds from the state general obligation bond issuance in the first quarter of 2007.

Deferred Fuel Costs

See Note 2 to the domestic utility companies and System Energy financial statements in the Form 10-K for information regarding fuel proceedings involving the domestic utility companies. The following are updates to the Form 10-K.

Entergy Arkansas

In March 2006, Entergy Arkansas filed with the APSC its annual redetermination of the energy cost rate for application to the period April 2006 through March 2007. The filed energy cost rate of $0.02827 per kWh was proposed to replace the interim rate of $0.01900 per kWh that had been in place since October 2005. The interim energy cost rate is discussed in Note 2 to the financial statements in the Form 10-K, along with the investigation that the APSC commenced concerning Entergy Arkansas' interim energy cost rate. The increase in the energy cost rate is due to increases in the cost of purchased power primarily due to the natural gas cost increase and the effect that Hurricanes Katrina and Rita had on market conditions, increased demand for purchased power during the ANO 1 refueling and steam generator replacement outage in the fall of 2005, and coal plant generation curtailments during off-peak periods due to railroad delivery problems.

On March 31, 2006, the APSC suspended implementation of the $0.02827 per kWh energy cost rate, and ordered that the $0.01900 per kWh interim rate remain in effect pending the APSC proceedings on the energy cost recovery filings. The APSC also extended its investigation into Entergy Arkansas' interim energy cost rate to cover the costs included in Entergy Arkansas' March 2006 filing. The extended investigation did not identify new issues in addition to the four issues listed in the Form 10-K and covers the same time period. On April 7, 2006, the APSC issued a show cause order in the investigation proceeding that ordered Entergy Arkansas to file a cost of service study by June 8, 2006. The order also directed Entergy Arkansas to file testimony to support the cost of service study, to support the $0.02827 per kWh cost rate, and to address the general topic of elimination of the energy cost recovery rider.

136

9;

In June 2006, Entergy Arkansas filed a motion with the APSC seeking again to implement the redetermined energy cost rate of $0.02827 per kWh. After a hearing, the APSC approved Entergy Arkansas' request and the redetermined rate was implemented in July 2006, subject to refund pending the outcome of the APSC energy cost recovery investigation. Because of the delay in implementing the redetermined energy cost rate, Entergy Arkansas estimated in its motion that $46 million of energy costs would remain under-recovered at December 31, 2006.

On June 7, 2006, Entergy Arkansas filed a cost of service study and testimony supporting the redetermined energy cost rate and testimony addressing the prospective elimination of the energy cost recovery rider as ordered by the APSC. A hearing was held in the APSC energy cost recovery investigation on October 12, 2006 and post-hearing briefs were filed by Entergy Arkansas, the APSC General Staff, the Arkansas Attorney General, and the Arkansas Electric Energy Consumers. No party recommended termination of the energy cost recovery rider in the fuel cost investigation proceeding. The timing of a decision in this proceeding is uncertain.

 

Entergy Gulf States

In March 2006, Entergy Gulf States filed with the PUCT an application to implement an interim fuel surcharge in connection with the under-recovery of $97 million including interest on eligible fuel costs for the period August 2005 through January 2006. This surcharge is in addition to an interim surcharge that went into effect in January 2006. Entergy Gulf States entered into a unanimous settlement that reduced the requested surcharge for actual over-collections from the months of February and March 2006, resulting in a surcharge of $78.8 million to be implemented over a twelve-month period beginning in June 2006. The PUCT approved the surcharge in June 2006. Entergy Gulf States has since entered into a joint agreement with several parties, which was approved by the PUCT, to remove the first interim fuel surcharge (the January 2006 surcharge) effective with the first billing cycle in November 2006. That surcharge was to be in effect until the end of 2006. Additionally, Entergy Gulf States requested that the PUCT remove the second interim surcharge (the June 2006 surcharge) as of November 2006 as well, which the PUCT has approved. Both of these requests are the result of over-recoveries in recent months. Amounts collected through the interim fuel surcharges are subject to final reconciliation in a future fuel reconciliation proceeding.

In May 2006, Entergy Gulf States filed with the PUCT a fuel and purchased power reconciliation case covering the period September 2003 through December 2005 for costs recoverable through the Texas fixed fuel factor rate and the incremental purchased capacity recovery rider. Entergy Gulf States is reconciling $1.6 billion of fuel and purchased power costs on a Texas retail basis. Hearings are scheduled for February 2007 and a PUCT decision is expected in July 2007.

Entergy Gulf States and Entergy Louisiana

In November 2005, the LPSC authorized its staff to initiate an expedited proceeding to audit the fuel and power procurement activities of Entergy Louisiana and Entergy Gulf States for the period January 1, 2005 through October 31, 2005. In April 2006, the LPSC accepted the LPSC Staff's audit report finding that the prices paid for natural gas and purchased power were reasonable and that given the market conditions surrounding Hurricanes Katrina and Rita, Entergy Louisiana and Entergy Gulf States acted reasonably and prudently in response to an extremely difficult environment.

Retail Rate Proceedings

See Note 2 to the domestic utility companies and System Energy financial statements in the Form 10-K for information regarding retail rate proceedings involving the domestic utility companies. The following are updates to the Form 10-K.

Filings with the APSC (Entergy Arkansas)

In August 2006, Entergy Arkansas filed with the APSC a request for a change in base rates. Entergy Arkansas requested a general base rate increase of $150 million (using an ROE of 11.25%), as well as recovery of FERC-allocated costs pursuant to the FERC decision on the System Agreement. Entergy Arkansas also requested a capacity management rider to recover incremental capacity costs. A procedural schedule has been established with hearings expected to begin in April 2007.

 

137

See Entergy Corporation and Subsidiaries' " MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - System Agreement Litigation " in the Form 10-K and herein for a discussion of Entergy's compliance filing in that proceeding. If the FERC approves the compliance tariff as filed, then payments under that tariff will be classified as energy costs, which would then be included in setting the retail energy cost rate as part of the normal working of the energy cost recovery rider.  As noted above, the APSC has given notice that it is considering the prospective elimination of the energy cost recovery rider.  Therefore, Entergy Arkansas proposed in the August 2006 base rate case an alternative to the energy cost recovery rider for recovery of the costs allocated to it as a result of the System Agreement litigation should the energy cost recovery rider be lawfully terminated by the APSC.  A separate exact recovery rider, similar to the energy cost recovery rider, would ensure that Entergy Arkansas customers pay only the amount allocated by the FERC.

Filings with the PUCT and Texas Cities (Entergy Gulf States)

As discussed in the Form 10-K, in August 2005, Entergy Gulf States filed with the PUCT an application for recovery of its transition to competition costs. Entergy Gulf States requested recovery of $189 million in transition to competition costs through implementation of a 15-year rider to be effective no later than March 1, 2006. The $189 million represents transition to competition costs Entergy Gulf States incurred from June 1, 1999 through June 17, 2005 in preparing for competition in its Texas service area, including attendant AFUDC, and all carrying costs projected to be incurred on the transition to competition costs through February 28, 2006. The $189 million is before any gross-up for taxes or carrying costs over the 15-year recovery period. Entergy Gulf States reached a unanimous settlement agreement on all issues with the active parties in the transition to competition cost recovery case. The agreement allows Entergy Gulf States to recover $14.5 million per year in transition to competition costs over a 15-year period. Entergy Gulf States implemented interim rates based on this revenue level on March 1, 2006. The PUCT approved the settlement agreement in June 2006.

Filings with the LPSC

Retail Rates - Electric

(Entergy Gulf States)

In March 2006, the LPSC approved an uncontested stipulated settlement in Entergy Gulf States' formula rate plan filing for the 2004 test year. The settlement includes a revenue requirement increase of $36.8 million and calls for Entergy Gulf States to apply a refund liability of $744 thousand to capacity deferrals. The refund liability pertained to the periods 2004-2005 as well as the interim period in which a $37.2 million revenue increase was in place.

In May 2006, Entergy Gulf States made its formula rate plan filing with the LPSC for the 2005 test year. Entergy Gulf States modified the filing in August 2006 to reflect an 11.1% return on equity which is within the allowed bandwidth. The modified filing includes a formula rate plan increase of $17.2 million which provides for interim recovery of storm costs from Hurricanes Katrina and Rita and recovery of LPSC-approved incremental deferred and ongoing capacity costs. The increase was implemented, subject to refund, with the first billing cycle of September 2006.

(Entergy Louisiana)

In May 2006, Entergy Louisiana made its formula rate plan filing with the LPSC for the 2005 test year. Entergy Louisiana modified the filing in August 2006 to reflect a 9.45% return on equity which is within the allowed bandwidth. The modified filing includes an increase of $24 million for

 

138

 

 interim recovery of storm costs from Hurricanes Katrina and Rita and a $120 million rate increase to recover LPSC-approved incremental deferred and ongoing capacity costs. The filing requested recovery of approximately $50 million for the amortization of capacity deferrals over a three-year period, including carrying charges, and approximately $70 million for ongoing capacity costs. The increase was implemented, subject to refund, with the first billing cycle of September 2006. Comments were provided by the LPSC Staff, which Entergy Louisiana is currently reviewing. Entergy Louisiana subsequently updated its formula rate plan rider to reflect adjustments proposed by the LPSC Staff with which it agrees. The adjusted return on equity of 9.56% remains within the allowed bandwidth. Ongoing and deferred incremental capacity costs were reduced to $119 million. The updated formula rate plan rider was implemented, subject to refund, with the first billing cycle of October 2006.

Retail Rates - Gas (Entergy Gulf States)

In January 2006, Entergy Gulf States filed with the LPSC its gas rate stabilization plan. The filing showed a revenue deficiency of $4.1 million based on an ROE mid-point of 10.5%. On May 1, 2006, Entergy Gulf States implemented a $3.5 million rate increase pursuant to an uncontested agreement with the LPSC Staff.

Filings with the MPSC (Entergy Mississippi)

Formula Rate Plan Filings

In March 2006, Entergy Mississippi made its annual scheduled formula rate plan filing with the MPSC.  The filing was amended by an April 2006 filing.  The amended filing showed that an increase of $3.1 million in electric revenues is warranted.  The MPSC approved a settlement providing for a $1.8 million rate increase, which was implemented in August 2006.

Filings with the City Council (Entergy New Orleans)

In June 2006, Entergy New Orleans made its annual formula rate plan filings with the City Council.  The filings presented various alternatives to reflect the effect of Entergy New Orleans' lost customers and decreased revenue. Entergy New Orleans' recommended alternative adjusts for lost customers and assumes that the City Council's June 2006 decision to allow recovery of all Grand Gulf costs through the fuel adjustment clause stays in place during the rate-effective period (a significant portion of Grand Gulf costs was previously recovered through base rates).

At the same time as it made its formula rate plan filings, Entergy New Orleans also filed with the City Council a request to implement two storm-related riders. With the first rider, Entergy New Orleans sought to recover the electric and gas restoration costs that it had actually spent through March 31, 2006. Entergy New Orleans also proposed semiannual filings to update the rider for additional restoration spending and also to consider the receipt of CDBG funds or insurance proceeds that it may receive. With the second rider, Entergy New Orleans sought to establish a storm reserve to provide for the risk of another storm.

In October 2006 the City Council approved a settlement agreement that resolves Entergy New Orleans' rate and storm-related rider filings by providing for phased-in rate increases, while taking into account with respect to storm restoration costs the anticipated receipt of CDBG funding as recommended by the Louisiana Recovery Authority. The settlement provides for a 0% increase in electric base rates through December 2007, with a $3.9 million increase implemented in January 2008. Recovery of all Grand Gulf costs through the fuel adjustment clause will continue. Gas base rates will increase by $4.75 million in November 2006, an additional $1.5 million in March 2007, and an additional $4.75 million in November 2007. The settlement calls for Entergy New Orleans to file a base rate case by July 31, 2008. Any storm costs in excess of CDBG funding and insurance proceeds will be addressed in that base rate case. A storm cost recovery rider is authorized but initially set at $0 because of the anticipated receipt of CDBG funding. The settlement also authorizes a $75 million storm reserve for damage from future storms, which will be created over a ten-year period through a storm reserve rider beginning in March 2007. These storm reserve funds will be held in a restricted escrow account.

139

Customer-Initiated Proceeding at the FERC (Entergy Arkansas)

As discussed in Part I, Item 1 of the Form 10-K, in September 2004, East Texas Electric Cooperative (ETEC) filed a complaint at the FERC against Entergy Arkansas relating to a contract dispute over the pricing of substitute energy at the co-owned Independence coal unit.  In October 2004, Arkansas Electric Cooperative (AECC) filed a similar complaint at the FERC against Entergy Arkansas, addressing the same issue with respect to Independence and another co-owned coal unit, White Bluff. FERC consolidated these cases, ordered a hearing in the consolidated proceeding, and established refund effective dates.  The main issue in the consolidated case relates to the consequences under the governing contracts when the dispatch of the coal units is constrained due to system operating conditions.  In August 2005, Entergy Arkansas and ETEC filed a settlement at the FERC that resolved all issues in dispute between ETEC and Entergy Arkansas. As part of the settlement, ETEC dismissed its complaint. A hearing was held on the AECC complaint and an ALJ Initial Decision was issued in January 2006 in which the ALJ found AECC's claims to be without merit. On October 25, 2006, the FERC issued an order on the ALJ's Initial Decision. In the order, the FERC reversed the ALJ's findings. Specifically, the FERC found that the governing contracts do not recognize the effects of dispatch constraints on the co-owned units. The FERC explained that for over twenty-three years the course of conduct of the parties was such that AECC received its full entitlement to the two coal units, regardless of any reduced output caused by system operating constraints. Based on the order, Entergy Arkansas is required to refund to AECC all excess amounts billed to AECC as a result of the system operating constraints. Entergy Arkansas estimates currently that this will result in a refund to AECC of approximately $26 million, although Entergy Arkansas is still refining the estimate. Requests for rehearing of the FERC's decision are due on November 24, 2006.

NOTE 3. LINES OF CREDIT, RELATED SHORT-TERM BORROWINGS, AND LONG-TERM DEBT

The short-term borrowings of the domestic utility companies (other than Entergy New Orleans) and System Energy are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through March 31, 2008. In addition to borrowing 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 Entergy's subsidiaries' dependence on external short-term borrowings. Borrowings from the money pool and external borrowings combined may not exceed the FERC authorized limits. There were no external short-term borrowings outstanding for the domestic utility companies and System Energy as of September 30, 2006. The following are the FERC-authorized limits for short-term borrowings effective February 2006 and the outstanding short-term borrowings from the money pool for the domestic utility companies (other than Entergy New Orleans) and System Energy as of September 30, 2006:

 

 

Authorized

 

Borrowings

 

 

(In Millions)

 

 

 

 

 

Entergy Arkansas

 

$250

 

-

Entergy Gulf States

 

$350

 

-

Entergy Louisiana

 

$250

 

$105.0

Entergy Mississippi

 

$175

 

-

System Energy

 

$200

 

-

Under a savings provision in PUHCA 2005, which repealed PUHCA 1935, Entergy New Orleans may continue to be a participant in the money pool to the extent authorized by its SEC PUHCA 1935 order. However, Entergy New Orleans has not, and does not expect to make, any additional money pool borrowings while it is in bankruptcy proceedings. Entergy New Orleans had $37.2 million in borrowings outstanding from the money pool as of its bankruptcy filing date, September 23, 2005. The money pool borrowings reflected on Entergy New Orleans' Balance Sheet as of September 30, 2006 are classified as a pre-petition obligation subject to compromise.

140

Entergy Arkansas, Entergy Gulf States, and Entergy Mississippi, each has credit facilities available as of September 30, 2006 as follows:


Company

 


Expiration Date

 

Amount of
Facility

 

Amount Drawn as of
September 30, 2006

 

 

 

 

 

 

 

Entergy Arkansas

 

April 2007

 

$85 million

 

-

Entergy Gulf States

 

February 2011

 

$50 million (a)

 

-

Entergy Mississippi

 

May 2007

 

$30 million (b)

 

-

Entergy Mississippi

 

May 2007

 

$20 million (b)

 

-

(a)

The credit facility allows Entergy Gulf States to issue letters of credit against the borrowing capacity of the facility. As of September 30, 2006, $1.4 million in letters of credit had been issued.

(b)

Borrowings under the Entergy Mississippi facilities may be secured by a security interest in its accounts receivable.

In May 2006, Entergy Mississippi increased its $25 million credit facility to $30 million and renewed it through May 2007. Entergy Mississippi also entered into a new $20 million credit facility through May 2007.

In addition, Entergy New Orleans, which is currently in bankruptcy and is no longer consolidated in Entergy's financial statements, had a 364-day credit facility in the amount of $15 million which expired in May 2006. In July 2006, the bankruptcy judge authorized Entergy New Orleans to set off $15 million of its cash held by the lender against the outstanding debt on the credit facility, and the setoff occurred in September 2006.

The credit facilities have variable interest rates and the average commitment fee is 0.13%. The $85 million Entergy Arkansas credit facility requires that it maintain total shareholders' equity of at least 25% of its total assets.

Entergy New Orleans Debtor-in-Possession Credit Facility

See Note 4 to the domestic utility companies and System Energy financial statements in the Form 10-K for a discussion of the Entergy New Orleans $200 million debtor-in-possession (DIP) credit facility. As discussed in the Form 10-K, the bankruptcy court issued its order in December 2005 giving final approval for the credit facility, and the indenture trustee for Entergy New Orleans' first mortgage bonds appealed the order. On March 29, 2006 the bankruptcy court approved a settlement among Entergy New Orleans, Entergy Corporation, and the indenture trustee, and the indenture trustee dismissed its appeal. As of September 30, 2006, Entergy New Orleans had approximately $32 million of outstanding borrowings under the DIP credit facility.

As discussed in the Form 10-K, borrowings under the DIP credit facility are due in full, and the agreement will terminate, at the earliest of several times or events, which included August 23, 2006. Entergy Corporation and Entergy New Orleans have agreed to an amendment to the DIP credit agreement that extends the August 23, 2006 maturity date to August 23, 2007.

The interest rate on borrowings under the DIP credit agreement will be the average interest rate of borrowings outstanding under Entergy Corporation's $2 billion revolving credit facility, which is currently approximately 5.8% per annum.

141

Long-term Debt

The following long-term debt has been issued by the domestic utility companies and System Energy in 2006:

 

Issue Date

 

Amount

 

 

 

(In Thousands)

Mortgage Bonds:

 

 

 

5.92% Series due February 2016 - Entergy Mississippi

January 2006

 

$100,000

Other Long-term Debt:

 

 

 

4.60% Series due October 2017, Jefferson County - Arkansas
 (Entergy Arkansas) (secured by a series of collateral first
 mortgage bonds)



June 2006



$54,700

The following long-term debt was retired by the domestic utility companies and System Energy in 2006:

 

Retirement Date

 

Amount

 

 

 

(In Thousands)

Other Long-term Debt:

 

 

 

5.95% Series due December 2023, St. Charles Parish - Louisiana
 (Entergy Louisiana)


June 2006  


$25,000

Grand Gulf Lease Obligation payment (System Energy)

N/A

$22,989

5.6% Series due October 2017, Jefferson County - Arkansas
 (Entergy Arkansas)


July 2006


$45,500

6.3% Series due June 2018, Jefferson County - Arkansas
 (Entergy Arkansas)


July 2006


$9,200

Entergy Mississippi used the proceeds from the January 2006 issuance to purchase the Attala power plant from Central Mississippi Generating Company, LLC and to repay short-term indebtedness.

Entergy Arkansas used the proceeds from the June 2006 issuance to redeem, prior to maturity, the $45.5 million of 5.6% Series of Jefferson County bonds and $9.2 million of 6.3% Series of Jefferson County bonds in July 2006. The issuance is shown as a non-cash transaction on the cash flow statement since the proceeds were placed in a trust and never held as cash by Entergy Arkansas.

NOTE 4. PREFERRED STOCK

(Entergy Arkansas)

In March 2006, Entergy Arkansas issued 3,000,000 shares of $25 par value 6.45% Series Preferred Stock, all of which were outstanding as of September 30, 2006. The dividends are cumulative and payable quarterly beginning July 1, 2006. The preferred stock is redeemable on or after April 1, 2011, at Entergy Arkansas' option, at the call price of $25 per share. In April 2006, Entergy Arkansas used the proceeds from this issuance to redeem the following preferred stock:

Series of Entergy Arkansas Preferred Stock

 

Redemption Price Per Share

     

7.32% Preferred Stock, Cumulative, $100.00 par value

 

$103.17

7.80% Preferred Stock, Cumulative, $100.00 par value

 

$103.25

7.40% Preferred Stock, Cumulative, $100.00 par value

 

$102.80

7.88% Preferred Stock, Cumulative, $100.00 par value

 

$103.00

$1.96 Preferred Stock, Cumulative, $0.01 par value

 

$ 25.00

142

(Entergy New Orleans)

Since the filing of the bankruptcy proceedings, Entergy New Orleans had not been able to declare and pay dividends on its 4.75% preferred stock for three quarters. As discussed further in the Form 10-K, if dividends with respect to the 4.75% preferred stock are not paid for four quarters, the holders of these shares have the right to elect a majority of the Entergy New Orleans board of directors.  Entergy New Orleans filed a motion in the bankruptcy court seeking authority to recommence paying dividends to the holders of the 4.75% preferred shares. After a hearing on the motion on May 3, 2006, the court granted Entergy New Orleans the authority to pay dividends to the holders of the 4.75% preferred shares, beginning with the dividend due on July 1, 2006, and thereafter, unless objections are filed by creditors forty-five days in advance of a dividend payment date. If any objections are filed, the matter would be heard by the bankruptcy court. Entergy New Orleans declared and paid the dividends due on July 1 and October 1, 2006, and intends to declare and pay the dividends on the 4.75% preferred shares each quarter pending resolution of its plan of reorganization.

NOTE 5. RETIREMENT AND OTHER POSTRETIREMENT BENEFITS

Components of Net Pension Cost

The domestic utility companies' and System Energy's qualified pension cost, including amounts capitalized, for the third quarters of 2006 and 2005, included the following components:

 

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

System

2006

 

Arkansas

 

Gulf States

 

Louisiana

 

Mississippi

 

New Orleans

 

Energy

 

 

(In Thousands)

Service cost - benefits earned

 

 

 

 

 

 

 

 

 

 

 

 

 during the period

 

$3,626 

 

$2,993 

 

$2,182 

 

$1,077 

 

$501 

 

$1,031 

Interest cost on projected

 

 

 

 

 

 

 

 

 

 

 

 

 benefit obligation

 

9,915 

 

7,914 

 

6,052 

 

3,252 

 

1,282 

 

1,604 

Expected return on assets

 

(9,834)

 

(10,176)

 

(7,114)

 

(3,683)

 

(884)

 

(1,775)

Amortization of prior service cost

 

415 

 

309 

 

141 

 

128 

 

56 

 

12 

Amortization of loss

 

2,438 

 

640 

 

1,509 

 

725 

 

509 

 

167 

Net pension cost

 

$6,560 

 

$1,680 

 

$2,770 

 

$1,499 

 

$1,464 

 

$1,039 

 

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

System

2005

 

Arkansas

 

Gulf States

 

Louisiana

 

Mississippi

 

New Orleans

 

Energy

 

 

(In Thousands)

Service cost - benefits earned

 

 

 

 

 

 

 

 

 

 

 

 

 during the period

 

$3,117 

 

$2,619 

 

$1,899 

 

$945 

 

$462 

 

$867 

Interest cost on projected

 

 

 

 

 

 

 

 

 

 

 

 

 benefit obligation

 

9,951 

 

7,863 

 

6,129 

 

3,312 

 

1,290 

 

1,437 

Expected return on assets

 

(8,910)

 

(10,005)

 

(6,675)

 

(3,579)

 

(972)

 

(1,452)

Amortization of transition asset

 

 

 

 

 

 

(69)

Amortization of prior service cost

 

417 

 

240 

 

120 

 

129 

 

57 

 

Amortization of (gain)/loss

 

2,331 

 

(390)

 

1,611 

 

597 

 

750 

 

207 

Net pension cost

 

$6,906 

 

$327 

 

$3,084 

 

$1,404 

 

$1,587 

 

$999 

143

 

The domestic utility companies' and System Energy's pension cost, including amounts capitalized, for the nine months ended September 30, 2006 and 2005, included the following components:

 

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

System

2006

 

Arkansas

 

Gulf States

 

Louisiana

 

Mississippi

 

New Orleans

 

Energy

 

 

(In Thousands)

Service cost - benefits earned

 

 

 

 

 

 

 

 

 

 

 

 

 during the period

 

$10,878 

 

$8,979 

 

$6,547 

 

$3,231 

 

$1,503 

 

$3,093 

Interest cost on projected

 

 

 

 

 

 

 

 

 

 

 

 

 benefit obligation

 

29,745 

 

23,743 

 

18,155 

 

9,756 

 

3,845 

 

4,813 

Expected return on assets

 

(29,501)

 

(30,527)

 

(21,341)

 

(11,050)

 

(2,651)

 

(5,326)

Amortization of prior service cost

 

1,246 

 

926 

 

422 

 

385 

 

169 

 

37 

Amortization of loss

 

7,313 

 

1,919 

 

4,527 

 

2,175 

 

1,527 

 

500 

Net pension cost

 

$19,681 

 

$5,040 

 

$8,310 

 

$4,497 

 

$4,393 

 

$3,117 

 

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

System

2005

 

Arkansas

 

Gulf States

 

Louisiana

 

Mississippi

 

New Orleans

 

Energy

 

 

(In Thousands)

Service cost - benefits earned

 

 

 

 

 

 

 

 

 

 

 

 

 during the period

 

$9,775 

 

$8,026 

 

$5,814 

 

$2,956 

 

$1,336 

 

$2,755 

Interest cost on projected

 

 

 

 

 

 

 

 

 

 

 

 

 benefit obligation

 

28,181 

 

22,333 

 

17,179 

 

9,309 

 

3,587 

 

4,262 

Expected return on assets

 

(26,927)

 

(29,422)

 

(20,008)

 

(10,712)

 

(2,435)

 

(4,099)

Amortization of transition asset

 

 

 

 

 

 

(208)

Amortization of prior service cost

 

1,248 

 

996 

 

445 

 

386 

 

170 

 

43 

Amortization of loss

 

5,556 

 

2,035 

 

3,072 

 

1,649 

 

1,052 

 

666 

Net pension cost

 

$17,833 

 

$3,968 

 

$6,502 

 

$3,588 

 

$3,710 

 

$3,419 

The domestic utility companies recognized the following pension cost for their non-qualified pension plans in the third quarters of 2006 and 2005:

 

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

 

Arkansas

 

Gulf States

 

Louisiana

 

Mississippi

 

New Orleans

(In Thousands)

Non-Qualified Pension Cost
 Third Quarter 2006

 


$125 

 


$319 

 


$6 

 


$43 

 


$55 

Non-Qualified Pension Cost
 Third Quarter 2005

 


$127 

 


$329 

 


$7 

 


$43 

 


$51 

The domestic utility companies recognized the following pension cost for their non-qualified pension plans for the nine months ended September 30, 2006 and 2005:

 

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

 

Arkansas

 

Gulf States

 

Louisiana

 

Mississippi

 

New Orleans

(In Thousands)

Non-Qualified Pension Cost Nine
 Months Ended September 30, 2006

 


$350 

 


$758 

 


$17 

 


$116 

 


$163 

Non-Qualified Pension Cost Nine
 Months Ended September 30, 2005

 


$330 

 


$922 

 


$18 

 


$117 

 


$153 

144

Components of Net Other Postretirement Benefit Cost

The domestic utility companies' and System Energy's other postretirement benefit cost, including amounts capitalized, for the third quarters of 2006 and 2005, included the following components:

 

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

System

2006

 

Arkansas

 

Gulf States

 

Louisiana

 

Mississippi

 

New Orleans

 

Energy

 

 

(In Thousands)

Service cost - benefits earned
 during the period

 


$1,337 

 


$1,254 

 


$854 

 


$419 

 


$232 

 


$414 

Interest cost on APBO

 

2,844 

 

2,747 

 

1,856 

 

944 

 

856 

 

407 

Expected return on assets

 

(1,797)

 

(1,489)

 

 

(709)

 

(611)

 

(421)

Amortization of transition obligation

 

205 

 

151 

 

96 

 

88 

 

416 

 

Amortization of prior service cost

 

(408)

 

 

(24)

 

(137)

 

10 

 

(301)

Amortization of loss

 

1,671 

 

1,002 

 

893 

 

644 

 

343 

 

207 

Net other postretirement benefit cost

 

$3,852 

 

$3,665 

 

$3,675 

 

$1,249 

 

$1,246 

 

$308 

 

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

System

2005

 

Arkansas

 

Gulf States

 

Louisiana

 

Mississippi

 

New Orleans

 

Energy

 

 

(In Thousands)

Service cost - benefits earned

 

 

 

 

 

 

 

 

 

 

 

 

 during the period

 

$1,167 

 

$1,017 

 

$789 

 

$369 

 

$210 

 

$447 

Interest cost on APBO

 

2,688 

 

2,313 

 

1,764 

 

918 

 

840 

 

390 

Expected return on assets

 

(1,626)

 

(1,269)

 

 

(669)

 

(579)

 

(390)

Amortization of transition obligation

 

204 

 

(48)

 

96 

 

87 

 

396 

 

Amortization of prior service cost

 

(642)

 

 

(66)

 

(228)

 

 

(198)

Amortization of loss

 

1,629 

 

657 

 

840 

 

675 

 

336 

 

168 

Net other postretirement benefit cost

 

$3,420 

 

$2,670 

 

$3,423 

 

$1,152 

 

$1,212 

 

$420 

The domestic utility companies' and System Energy's other postretirement benefit cost, including amounts capitalized, for the nine months ended September 30, 2006 and 2005, included the following components:

 

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

System

2006

 

Arkansas

 

Gulf States

 

Louisiana

 

Mississippi

 

New Orleans

 

Energy

 

 

(In Thousands)

Service cost - benefits earned
 during the period

 


$4,010 

 


$3,761 

 


$2,561 

 


$1,256 

 


$696 

 


$1,242 

Interest cost on APBO

 

8,531 

 

8,242 

 

5,569 

 

2,833 

 

2,569 

 

1,220 

Expected return on assets

 

(5,390)

 

(4,466)

 

 

(2,127)

 

(1,832)

 

(1,263)

Amortization of transition obligation

 

616 

 

453 

 

287 

 

263 

 

1,247 

 

Amortization of prior service cost

 

(1,223)

 

 

(73)

 

(410)

 

29 

 

(903)

Amortization of loss

 

5,013 

 

3,006 

 

2,682 

 

1,931 

 

1,028 

 

620 

Net other postretirement benefit cost

 

$11,557 

 

$10,996 

 

$11,026 

 

$3,746 

 

$3,737 

 

$923 

145

 

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

System

2005

 

Arkansas

 

Gulf States

 

Louisiana

 

Mississippi

 

New Orleans

 

Energy

 

 

(In Thousands)

Service cost - benefits earned

 

 

 

 

 

 

 

 

 

 

 

 

 during the period

 

$3,481 

 

$4,284 

 

$2,167 

 

$1,096 

 

$595 

 

$1,278 

Interest cost on APBO

 

7,865 

 

8,162 

 

5,110 

 

2,584 

 

2,417 

 

1,178 

Expected return on assets

 

(4,899)

 

(4,001)

 

 

(2,010)

 

(1,737)

 

(1,163)

Amortization of transition obligation

 

615 

 

1,847 

 

287 

 

263 

 

1,267 

 

11 

Amortization of prior service cost

 

(988)

 

 

(30)

 

(320)

 

28 

 

(477)

Amortization of loss

 

4,181 

 

2,196 

 

2,221 

 

1,619 

 

758 

 

459 

Net other postretirement benefit cost

 

$10,255 

 

$12,488

 

$9,755 

 

$3,232 

 

$3,328 

 

$1,286 

Employer Contributions

The domestic utility companies and System Energy expect to contribute the following to pension plans in 2006. A portion of these contributions were planned to be made in 2005, but were delayed until January 2006 in accordance with the Katrina Emergency Tax Relief Act. For further information on pension funding refer to Note 10 to the domestic utility companies and System Energy's financial statements in the Form 10-K.

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

System

 

 

Arkansas

 

Gulf States

 

Louisiana

 

Mississippi

 

New Orleans

 

Energy

 

 

(In Thousands)

Expected 2006 pension contributions
 disclosed in Form 10-K

 


$114,544

 


$22,102

 


$54,048

 


$16,357

 


$ -

 


$13,037

Pension contributions made through
 October 2006

 

$114,544

 

$22,102

 


$54,048

 

$16,357

 

$ -

 

$13,609

The Pension Protection Act of 2006 was signed by the President on August 17, 2006. The intent of the legislation is to require companies to fund 100% of their pension liability; and then for companies to fund, on a going-forward basis, an amount generally estimated to be the amount that the pension liability increases each year due to an additional year of service by the employees eligible for pension benefits. The legislation requires that funding shortfalls be eliminated by companies over a seven-year period, beginning in 2008. The Pension Protection Act also extended the provisions of the Pension Funding Equity Act that would have expired in 2006 had the Pension Protection Act not been enacted, which increased the allowed discount rate used to calculate the pension funding liability. Entergy is in the process of evaluating the effects of the new legislation, but expects that the implementation of the Pension Protection Act will not result in annual pension contributions going-forward that are materially higher than the levels required in 2005 and 2006.

146

Medicare Prescription Drug, Improvement and Modernization Act of 2003 (Medicare Act)

Based on actuarial analysis, the estimated effect of future Medicare subsidies reduced the December 31, 2005 Accumulated Postretirement Benefit Obligation (APBO), the third quarters 2006 and 2005 other postretirement benefit cost, and the nine months ended September 30, 2006 and 2005 for the domestic utility companies and System Energy as follows:

 

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

Entergy

 

System

 

 

Arkansas

 

Gulf States

 

Louisiana

 

Mississippi

 

New Orleans

 

Energy

 

 

(In Thousands)

Reduction in 12/31/2005 APBO

 

($42,337)

 

($36,740)

 

($23,640)

 

($14,407)

 

($11,206)

 

($5,972)

Reduction in third quarter 2006
 other postretirement benefit cost

 


($1,562)

 


($1,332)

 


($865)

 


($512)

 


($376)

 


($268)

Reduction in third quarter 2005
 other postretirement benefit cost

 


($1,275)

 


($1,104)

 


($729)

 


($420)

 


($318)

 


($225)

Reduction in nine months ended
 September 30, 2006 other
 postretirement benefit cost



($4,685)

 



($3,996)

 



($2,595)

 



($1,535)

 



($1,127)

 



($803)

Reduction in nine months ended
 September 30, 2005 other
 postretirement benefit cost



($4,167)

 



($3,642)

 



($2,309)

 



($1,371)

 



($1,017)

 



($714)

Medicare subsidies received in the
 third quarter 2006 for claims
 through June 2006



$374 

 



$462 

 



$298 

 



$163 

 



$165 

 



$35 

For further information on the Medicare Act refer to Note 10 to the domestic utility companies and System Energy's financial statements in the Form 10-K.

NOTE 6. ENTERGY NEW ORLEANS BANKRUPTCY PROCEEDING

See Note 14 to the domestic utility companies and System Energy financial statements in the Form 10-K for a discussion of the Entergy New Orleans bankruptcy proceeding. Following are updates to that discussion.

As discussed in the Form 10-K, the bankruptcy court issued its order in December 2005 giving final approval for the $200 million debtor-in-possession (DIP) credit facility, and the indenture trustee for Entergy New Orleans' first mortgage bonds appealed the order. On March 29, 2006 the bankruptcy court approved a settlement among Entergy New Orleans, Entergy Corporation, and the indenture trustee, and the indenture trustee dismissed its appeal.

On October 23, 2006 Entergy New Orleans filed a plan of reorganization and a disclosure statement with the bankruptcy court. Objections to the disclosure statement must be filed by November 29, 2006, and a hearing regarding its adequacy is scheduled for December 7, 2006. The period within which Entergy New Orleans has the exclusive right to solicit acceptance of its plan of reorganization will expire on December 22, 2006, unless it is further extended by the bankruptcy court.

The bankruptcy court also extended the time within which Entergy New Orleans has an exclusive right to file a plan of reorganization until November 15, 2006. Financial Guaranty Insurance Company (FGIC), the insurer of two series totaling $75 million of Entergy New Orleans' first mortgage bonds, filed a motion to terminate the exclusive period within which Entergy New Orleans has an exclusive right to file and solicit acceptances of a plan of reorganization. FGIC asks the court to allow itself or other stakeholders the right to file an alternative and competing plan of reorganization and to solicit acceptances for such a proposed plan. FGIC's motion to terminate exclusivity is set for hearing on November 15, 2006.

147

The plan of reorganization reflects Entergy New Orleans' continuing effort to work with federal, state, and local authorities to resolve the bankruptcy in a manner that allows Entergy New Orleans' customers to be served by a financially viable entity as required by law. The plan of reorganization also provides full compensation to Entergy New Orleans' creditors whose claims are allowed by the bankruptcy court. Conditions precedent proposed in the plan of reorganization, as currently filed, before it can become effective include:

  • A final confirmation order from the bankruptcy court approving the plan of reorganization;
  • Implementation of a City Council resolution that is satisfactory to Entergy New Orleans regarding its formula rate plan gas and electric filings and its proposed storm cost recovery and storm reserve riders;
  • Receipt by Entergy New Orleans of insurance proceeds of at least $250 million or assurance of such receipt, or alternatively, assurance that regulatory mechanisms will be put in place to cover any shortfall in insurance proceeds;
  • Receipt by Entergy New Orleans of $200 million in CDBG funding and assurance that at a minimum an additional $200 million in CDBG funding will be available for future gas system rebuild or assurance from the City Council that an appropriate rate mechanism is in place to allow Entergy New Orleans to recover the costs thereof;
  • No material adverse change shall have occurred from and after the confirmation date of the plan of reorganization; and
  • Entergy New Orleans receives a final order from the FERC authorizing issuance of short-term debt securities under credit agreements, the Entergy System money pool, and unilateral arrangements with Entergy Corporation.

In addition, key factors that will continue to influence the timing and outcome of Entergy New Orleans' recovery efforts include the level of economic recovery of New Orleans and the number of customers that return to New Orleans, including the timing of their return. Entergy New Orleans currently estimates that approximately 85,000 electric customers and 65,000 gas customers have returned and are taking service. Prior to Hurricane Katrina, Entergy New Orleans had approximately 190,000 electric customers and 145,000 gas customers.

The bankruptcy judge set a date of April 19, 2006 by which creditors with pre-petition claims against Entergy New Orleans, with certain exceptions, had to file their proofs of claim in the bankruptcy case. Approximately 550 claims, including amending claims, have been filed thus far in Entergy New Orleans' bankruptcy proceeding. Entergy New Orleans is currently analyzing the accuracy and validity of the claims filed, and has begun seeking withdrawal or modification of claims or objecting to claims with which it disagrees. Several of the filed claims have been withdrawn. Entergy New Orleans currently estimates that the pre-petition claims that will be allowed in the bankruptcy case will approximate the pre-petition liabilities that have been classified as liabilities subject to compromise in Entergy New Orleans' Balance Sheet as of September 30, 2006. The following table summarizes the components of liabilities subject to compromise as of September 30, 2006 and December 31, 2005:

   

September 30, 2006

 

December 31, 2005

   

(In Thousands)

         

Accounts payable - Associated companies

 

$66,820

 

$46,815

Accounts payable - Other

 

26,000

 

25,000

Taxes accrued

 

2,027

 

2,027

Interest accrued

 

1,744

 

1,473

Accumulated provisions

 

5,802

 

5,770

Long-term debt

 

229,871

 

229,859

Total Liabilities Subject to Compromise

 

$332,264

 

$310,944

The plan of reorganization proposes to pay the third party accounts payable in full in cash, to issue two-year notes in satisfaction of the affiliate accounts payable, and proposes that the first mortgage bonds will remain outstanding with their current maturity dates and interest terms. The plan of reorganization proposes that Entergy New Orleans' preferred stock will also remain outstanding on its current dividend terms.

148

Reorganization items on Entergy New Orleans' Income Statements for the three and nine months ended September 30, 2006 primarily consists of professional fees associated with the bankruptcy case.

The accompanying financial statements have been prepared on the basis that Entergy New Orleans will continue as a going concern. Entergy New Orleans' filing for protection under Chapter 11 of the United States Bankruptcy Code as a result of the liquidity issues caused by Hurricane Katrina gives rise to substantial doubt regarding Entergy New Orleans' ability to continue as a going concern for a reasonable period of time, primarily because of the loss of control inherent in the bankruptcy process. The financial statements do not include any adjustments that might result from the outcome of this uncertainty including adjustments relating to the recoverability and classification of recorded asset amounts or to the amounts and classification of liabilities that may be necessary if Entergy New Orleans is unable to continue as a going concern. The financial statements also do not attempt to reflect liabilities at the priority or status of any claims that the holders of such liabilities will have.

NOTE 7. ACCOUNTING POLICY UPDATES

Revenue and Fuel Costs

Entergy recognizes revenue from electric power and gas sales when it delivers power or gas to its customers. To the extent that deliveries have occurred but a bill has not been issued, the domestic utility companies accrue an estimate of the revenues for energy delivered since the latest billings. Entergy calculates the estimate based upon several factors including billings through the last billing cycle in a month, actual generation in the month, historical line loss factors, and prices in effect in the domestic utility companies' various jurisdictions. Changes are made to the inputs in the estimate as needed to reflect changes in billing practices.  Modifications made to the billing system in the third quarter 2006 provide better information related to the amount of generation that remains unbilled at the end of each month. Accordingly, the domestic utility companies refined the calculation of unbilled revenue to reflect this additional information. This refinement added to unbilled revenue in the third quarter 2006 the following amounts: $9.1 million for Entergy Arkansas, $2.7 million for Entergy Gulf States, $4.7 million for Entergy Louisiana, $5.5 million for Entergy Mississippi, and $3.6 million for Entergy New Orleans.  Each month the estimated unbilled revenue amounts are recorded as revenue and unbilled accounts receivable, and the prior month's estimate is reversed. Therefore, changes in price and volume differences resulting from factors such as weather affect the calculation of unbilled revenues from one period to the next, and may result in variability in reported revenues from one period to the next as prior estimates are so recorded and reversed.

Prior to 2006, Entergy Louisiana and the Louisiana portion of Entergy Gulf States included a component of fuel cost recovery in their unbilled revenue calculations. Effective January 1, 2006, this fuel component of unbilled accounts receivable was reclassified to deferred fuel and is no longer included in the unbilled revenue calculations for Entergy Louisiana and the Louisiana portion of Entergy Gulf States, which is in accordance with regulatory treatment.

Application of SFAS 71

During 2005 and 2006 Entergy filed notices with the FERC to withdraw its market-based rate authority for wholesale transactions in the Entergy control area and submitted new cost-based rates to the FERC for approval. During the second quarter of 2006, the FERC issued an order accepting the cost-based rates filed by Entergy. As described further in Note 1 to the domestic utility companies and System Energy financial statements in the Form 10-K, the domestic utility companies and System Energy apply the provisions of SFAS 71 to operations that meet three criteria including that rates are approved by a regulator, are cost-based, and can be charged to and collected from customers. As also described in Note 1 to the domestic utility companies and System Energy financial statements in the Form 10-K, Entergy Gulf States did not apply regulatory accounting principles to its wholesale jurisdiction. The FERC decision in the second quarter of 2006 results in Entergy Gulf States meeting the SFAS 71 criteria discussed above for its wholesale jurisdiction and, therefore, Entergy Gulf States reinstated the application of regulatory accounting principles to its wholesale business which resulted in a regulatory credit of approximately $4.5 million during the second quarter of 2006.

149

Recently Issued Accounting Pronouncements

FASB Interpretation No. 48, "Accounting for Uncertainty in Income Taxes" (FIN 48) was issued in July 2006 and is effective for Entergy in the first quarter of 2007. The FASB's objective in issuing this interpretation is to increase comparability among companies in financial reporting of income taxes. FIN 48 establishes a "more-likely-than-not" recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return, but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. Entergy does not expect that the adoption of FIN 48 will materially affect its financial position, results of operations, or cash flows.

In September 2006, FASB issued SFAS 158, "Employers' Accounting for Defined Benefit Pension and Other Postretirement Plans, an amendment of FASB Statements Nos. 87, 88, 106 and 132(R)," to be effective December 31, 2006. SFAS 158 requires employers to recognize the overfunded or underfunded status of a defined benefit postretirement plan as an asset or liability in its balance sheet with the offset recorded to other comprehensive income. Entergy has previously disclosed its funded status in Note 10 to the consolidated financial statements in the Form 10-K. SFAS 158 also requires that changes in that funded status be recorded in other comprehensive income in the period in which the changes occur. The domestic utility companies, with the exception of the Louisiana jurisdictions which provide for recovery of other postretirement benefit costs on a pay as you go basis, is generally allowed to recover pension and other postretirement benefit costs each period based upon costs calculated under SFAS 87 and SFAS 106. Entergy's analysis, including the regulatory accounting requirements to support recording the majority of the effect of adoption of SFAS 158 as a regulatory asset, is not yet complete.  Entergy does not expect the implementation of this standard, however, to materially affect Entergy's financial position or results of operations.

__________________________________

In the opinion of the management of Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, 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 domestic utility companies 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, 2006, evaluations were performed under the supervision and with the participation of Entergy Corporation, Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy Resources (individually "Registrant" and collectively the "Registrants") management, including their respective Chief Executive Officers (CEO) and Chief Financial Officers (CFO). The evaluations assessed the effectiveness of the Registrants' disclosure controls and procedures. Based on the evaluations, each CEO and CFO has concluded that, as to the Registrant or Registrants for which they serve as CEO or CFO, 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 CEOs and CFOs, as appropriate to allow timely decisions regarding required disclosure.

150

 

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 proceedings affecting Entergy. Following are updates to that discussion.

Texas Power Price Lawsuit

See "Texas Power Price Lawsuit" in Part I, Item 1 of the Form 10-K for a discussion of the lawsuit filed in the district court of Chambers County, Texas by Texas residents on behalf of a purported class apparently of the Texas retail customers of Entergy Gulf States who were billed and paid for electric power from January 1, 1994 to the present. In April 2006, the Court of Appeals denied a motion for rehearing of the decision to remand the case to the district court.  In May 2006, Entergy filed a petition for discretionary review with the Texas Supreme Court, which is still pending. The Texas Supreme Court requested full briefing from the parties before consideration of whether to exercise its discretion to grant review of this matter.

Entergy New Orleans Rate of Return Lawsuit and Entergy New Orleans Fuel Clause Litigation

See "Entergy New Orleans Rate of Return Lawsuit" in Part I, Item 1 of the Form 10-K for a discussion of the lawsuit filed by a group of residential and business ratepayers against Entergy New Orleans in state court in Orleans Parish purportedly on behalf of all ratepayers in New Orleans.  In accordance with the procedural schedule, the evidentiary record and post-hearing briefs of the parties were submitted to the City Council in March 2006. In April 2006, the City Council unanimously approved a resolution dismissing with prejudice the plaintiffs' claims. The plaintiffs appealed the resolution to the Civil District Court for the Parish of Orleans. The district court has not yet issued a procedural schedule for the appeal.

Additionally, in the Entergy New Orleans bankruptcy proceeding, the complaint filed by the named plaintiffs in the Entergy New Orleans rate of return lawsuit, together with the named plaintiffs in the Entergy New Orleans fuel clause lawsuit, asking the court to declare that Entergy New Orleans, Entergy Corporation, and Entergy Services are a single business enterprise, and as such, are liable in solido with Entergy New Orleans for any claims asserted in the Entergy New Orleans rate of return lawsuit and the Entergy New Orleans fuel clause lawsuit, was dismissed on April 26, 2006. The matter was appealed to the U.S. District Court for the Eastern District of Louisiana, and the district court affirmed the dismissal in October 2006, but on different grounds, concluding that the lawsuit was premature. In addition, in April 2006, proofs of claim were filed by the plaintiffs in the Entergy New Orleans rate of return lawsuit and by the plaintiffs in the Entergy New Orleans fuel adjustment clause litigation relating to both the City Council and class action proceedings. The plaintiffs in the Entergy New Orleans rate of return lawsuit and the plaintiffs in the Entergy New Orleans fuel adjustment clause litigation also filed for class certification. In July 2006, the bankruptcy court denied the request for class certification. The individual claims of the approximately 14 individual named plaintiffs remain pending in the bankruptcy proceeding, and it is uncertain whether the bankruptcy judge will re-open the bar date for other ratepayers to file individual proofs of claim based on the allegations in the two lawsuits.

Murphy Oil Lawsuit (Entergy Corporation and Entergy Louisiana)

See "Murphy Oil Lawsuit" in Part I, Item 1 of the Form 10-K for a discussion of the several lawsuits filed in state court in St. Bernard Parish, Louisiana against Murphy Oil, Entergy Louisiana, and others for injuries they allegedly suffered as a result of an explosion at the refinery in June 1995. Claiborne P. Deming, who became a director of Entergy Corporation in 2002, is the President and Chief Executive Officer of Murphy Oil. Mr. Deming did not stand for re-election to the Entergy Corporation Board of Directors and his term expired in May 2006. In June 2006, the Louisiana Fourth Circuit Court of Appeal affirmed the trial court's allocation of fault against Entergy Louisiana, but reduced the amount of damages owed by Entergy Louisiana to approximately $1.2 million.

151

Environmental Regulation and Proceedings

(Entergy Corporation)

On April 19, 2006, an environmental advocacy organization served a notice of intent to bring an environmental citizen's suit pursuant to the federal Resource Conservation and Recovery Act (RCRA) against Entergy.  Notice of suit is required by RCRA sixty days before actual filing.  The suit, if filed, will allege that Entergy violated an EPA regulation by failing formally to report a discovered release of radioactive material into the environment at Indian Point.  These allegations relate to the ongoing site investigation of radionuclides found in groundwater wells at the site.  It is expected that the environmental advocacy organization will ask the court to require Entergy formally to notify EPA of the site condition, will seek to have EPA formally involved in the ongoing site investigation and any required remediation, will seek attorney's fees under the statute, and may seek to have the judge impose statutory penalties. Entergy continues to investigate the matter.

(Entergy Corporation and Entergy Gulf States)

The Texas Commission on Environmental Quality (Commission) has notified Entergy Gulf States that the Commission believes, based on a preliminary investigation, that Entergy Gulf States is a potentially responsible party (PRP) concerning contamination existing at the Spector Salvage Yard proposed state superfund site in Orange County, Texas. The Commission currently is proposing soil removal activities at the site. Entergy Gulf States is communicating with the Commission and investigating its possible past involvement with this site. Current estimates for remediation costs and for allocation of that cost among PRPs are not available.

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

In accordance with Entergy's stock-based compensation plans, Entergy periodically grants stock options to its employees that 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.  See Note 7 to the consolidated financial statements in the Form 10-K for additional discussion of the stock-based compensation plans.  Entergy's management has been authorized to repurchase on the open market shares up to an amount sufficient to fund the exercise of grants under the plans, and this authorization does not have an expiration date.  In August 2004, Entergy announced a program under which Entergy Corporation will repurchase up to $1.5 billion of its common stock.  This repurchase program is incremental to the existing authority to repurchase shares to fund the exercise of employee stock options.  As a result of Hurricanes Katrina and Rita, the $1.5 billion program was temporarily suspended, and the Board extended authorization for its completion through 2008.  At any point in time through 2008, Entergy Corporation may elect to repurchase shares to complete the remaining $400 million of authorization under the $1.5 billion program or to fund the exercise of grants under its employee based compensation plans.  Entergy Corporation did not repurchase any shares of common stock during the nine months ended September 30, 2006, but began repurchasing shares again in the fourth quarter 2006.

152

Item 5. Other Information

Generation

As discussed in Part I, Item 1 of the Form 10-K, Property and Other Generation Resources , Entergy Louisiana and Entergy New Orleans currently have three long-term contracts to procure electric power from affiliates, as follows: (a) a life-of-unit purchased power agreement with Entergy Gulf States for approximately 200 MW (Entergy Louisiana) and 100 MW (Entergy New Orleans) of capacity and associated energy from Entergy Gulf States' River Bend nuclear station (the "RB PPAs"); (ii) a life-of-unit purchased power agreement with Entergy Arkansas for 110 MW each of capacity and associated energy from a portion of Entergy Arkansas' wholesale base load coal and nuclear generating resources (the "WBL PPAs"); and (iii) a life-of-unit purchased power agreement for approximately 50 MW each of capacity and associated energy from Entergy Power's share of the Independence plant (the "ISES PPAs"). The contracts were filed with the FERC, and the FERC had established a hearing process to review the justness and reasonableness of the agreements. After hearings were held, the FERC ALJ issued an initial decision generally recommending approval of the PPAs.

In September 2006, the FERC issued an order in the proceeding that: (1) affirmed the ALJ's initial decision that the RB PPAs, WBL PPAs, and the ISES PPAs were just, reasonable, and not unduly discriminatory; however, the FERC did limit the term of the ISES PPAs to ten years to coincide with the ten-year analysis used to justify those contracts; (2) determined that the domestic utility companies improperly used information obtained through their 2002 Request For Proposals (RFP) process to price the WBL PPAs, which FERC found to be a violation of Entergy's code of conduct, and ordered Entergy Arkansas' retained share of Grand Gulf be removed from the WBL PPAs, but approved the remaining portion of the WBL PPAs; (3) indicated that Entergy Arkansas' retained share of Grand Gulf could be separately contracted for by Entergy Louisiana and Entergy New Orleans "at the cost-based price of $46 per MWh;" (4) agreed with the ALJ that "the design and implementation of Entergy's RFP process, while not without flaws, worked in this instance;" (5) ordered the domestic utility companies to consider transmission costs "as a price factor" and that future analysis compare the delivered cost of the resource when evaluating RFP bids; and (6) approved the Entergy System's allocation of the PPAs among the domestic utility companies. On October 26, 2006, the domestic utility companies filed with the FERC a request for rehearing/clarification on the issues of the shortening of the term of the ISES PPAs, the finding of a violation of Entergy's code of conduct, and the finding that the cost-based rate for Entergy Arkansas' retained share of the Grand Gulf capacity is $46 per MWh.

Other Customer-Initiated Proceedings at the FERC

The Louisiana Energy and Power Authority ("LEPA") filed a Petition and Application for Order Directing Transmission Service under Section 211 of the Federal Power Act against Entergy Services (as agent for the domestic utility companies) and Cleco Power LLC. LEPA's petition requests that the FERC require the domestic utility companies and Cleco to allow LEPA to use its existing pre-FERC Order No. 888 transmission service to transmit power from new generating resources. LEPA argued that it should not be held responsible for the cost of any transmission upgrades on either the Entergy or Cleco transmission system that are necessary to make the new generation resources deliverable under the Open Access Transmission Tariff (OATT). In September 2006, the FERC issued an order dismissing and denying the complaint filed by LEPA. Specifically, the FERC denied LEPA's request to convert or roll over its existing pre-FERC Order No. 888 transmission service. Instead, the FERC explained that in effect, LEPA requested new service and that the domestic utility companies properly considered this new transmission service request under the OATT. The FERC pointed out that the domestic utility companies' studies showed that the new service requires transmission upgrades and LEPA is required to pay the higher of either the domestic utility companies' embedded costs (rolled-in rate) or the incremental costs of the system upgrade if it wants the OATT service. LEPA has requested rehearing of the FERC's decision.

153

Earnings Ratios (Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

The domestic utility companies and System Energy 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,

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

Entergy Arkansas

3.29

 

2.79

 

3.17

 

3.37

 

3.75

 

3.34

Entergy Gulf States

2.36

 

2.49

 

1.51

 

3.04

 

3.34

 

3.04

Entergy Louisiana

2.76

 

3.14

 

3.93

 

3.60

 

3.50

 

3.43

Entergy Mississippi

2.14

 

2.48

 

3.06

 

3.41

 

3.16

 

2.73

Entergy New Orleans

(a)

 

(b)

 

1.73

 

3.60

 

1.22

 

1.95

System Energy

2.12

 

3.25

 

3.66

 

3.95

 

3.85

 

4.06

   

 

Ratios of Earnings to Combined Fixed Charges
and Preferred Dividends/Distributions

 

Twelve Months Ended

 

December 31,

 

September 30,

 

2001

 

2002

 

2003

 

2004

 

2005

 

2006

                       

Entergy Arkansas

2.99

 

2.53

 

2.79

 

2.98

 

3.34

 

3.01

Entergy Gulf States

2.21

 

2.40

 

1.45

 

2.90

 

3.18

 

2.92

Entergy Louisiana

2.76

 

3.14

 

3.93

 

3.60

 

3.50

 

3.15

Entergy Mississippi

1.96

 

2.27

 

2.77

 

3.07

 

2.83

 

2.52

Entergy New Orleans

(a)

 

(b)

 

1.59

 

3.31

 

1.12

 

1.80

(a)

Earnings for the twelve months ended December 31, 2001, for Entergy New Orleans were not adequate to cover fixed charges and combined fixed charges and preferred dividends by $6.6 million and $9.5 million, respectively.

(b)

Earnings for the twelve months ended December 31, 2002, for Entergy New Orleans were not adequate to cover fixed charges and combined fixed charges and preferred dividends by $0.7 million and $3.4 million, respectively.

Item 6. Exhibits *

 

3(a) -

Restated Certificate of Incorporation of Entergy Corporation dated October 10, 2006.

     

**

3(b) -

By-laws of Entergy Corporation as amended September 19, 2006 (Exhibit 3 to Form 8-K dated September 25, 2006 in 1-11299).

     
 

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.

 

154

 

 

31(e) -

Rule 13a-14(a)/15d-14(a) Certification for Entergy Gulf States.

     
 

31(f) -

Rule 13a-14(a)/15d-14(a) Certification for Entergy Gulf States.

     
 

31(g) -

Rule 13a-14(a)/15d-14(a) Certification for Entergy Gulf States.

     
 

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 Louisiana.

     
 

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 Mississippi.

     
 

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 New Orleans.

     
 

31(n) -

Rule 13a-14(a)/15d-14(a) Certification for System Energy.

     
 

31(o) -

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.

     
 

32(f) -

Section 1350 Certification for Entergy Gulf States.

     
 

32(g) -

Section 1350 Certification for Entergy Gulf States.

     
 

32(h) -

Section 1350 Certification for Entergy Louisiana.

     
 

32(i) -

Section 1350 Certification for Entergy Louisiana.

     
 

32(j) -

Section 1350 Certification for Entergy Mississippi.

     
 

32(k) -

Section 1350 Certification for Entergy Mississippi.

     
 

32(l) -

Section 1350 Certification for Entergy New Orleans.

     
 

32(m) -

Section 1350 Certification for Entergy New Orleans.

     
 

32(n) -

Section 1350 Certification for System Energy.

     
 

32(o) -

Section 1350 Certification for System Energy.

     
 

99(a) -

Entergy Arkansas' Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Dividends, as defined.

     
 

99(b) -

Entergy Gulf States' Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Dividends, as defined.

 

155

 

 

 

99(c) -

Entergy Louisiana, LLC's Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Distributions, as defined.

     
 

99(d) -

Entergy Mississippi's Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Dividends, as defined.

     
 

99(e) -

Entergy New Orleans' Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Dividends, as defined.

     
 

99(f) -

System Energy's Computation of Ratios of Earnings to Fixed Charges, as defined.

___________________________

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.

*

Reference is made to a duplicate list of exhibits being filed as a part of this report on Form 10-Q for the quarter ended September 30, 2006, which list, prepared in accordance with Item 102 of Regulation S-T of the SEC, immediately precedes the exhibits being filed with this report on Form 10-Q for the quarter ended September 30, 2006.

**

Incorporated herein by reference as indicated.

156

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, INC.
ENTERGY LOUISIANA, LLC
ENTERGY MISSISSIPPI, INC.
ENTERGY NEW ORLEANS, INC.
SYSTEM ENERGY RESOURCES, INC.

 

/s/ Nathan E. Langston
Nathan E. Langston
Senior Vice President and Chief Accounting Officer
(For each Registrant and for each as
Principal Accounting Officer)

 

Date: November 8, 2006

157

Exhibit 3(a)

RESTATED
CERTIFICATE OF INCORPORATION
OF
ENTERGY CORPORATION

Entergy Corporation, a corporation organized and existing under the laws of the State of Delaware, hereby certifies as follows:

  1. The name of the Corporation is Entergy Corporation and the name under which the corporation was originally incorporated is Entergy-GSU Holdings, Inc.
  2. The original Certificate of Incorporation of this corporation was filed with the Secretary of State of Delaware on August 19, 1992.
  3. This Restated Certificate of Incorporation only restates and integrates and does not further amend the provisions of the Certificate of Incorporation of this corporation as heretofore amended or supplemented and there is no discrepancy between those provisions and the provisions of this Restated Certificate of Incorporation.
  4. The text of the Certificate of Incorporation as amended or supplemented heretofore is hereby restated without further amendments or changes to read as herein set forth in full:
  5. This Restated Certificate of Incorporation was duly adopted by the Board of Directors in accordance with Section 245 of the General Corporation Law of the State of Delaware.

FIRST : The name of the Corporation is Entergy Corporation (hereinafter the "Corporation").

SECOND : The address of the registered office of the Corporation in the State of Delaware is 1209 Orange Street, in the City of Wilmington, County of New Castle. The name of its registered agent at that address is The Corporation Trust Company.

THIRD : The purpose of the Corporation is to engage in any lawful act or activity for which a corporation may be organized under the General Corporation Law of the State of Delaware as set forth in Title 8 of the Delaware Code.

FOURTH : The total number of shares of stock which the Corporation shall have authority to issue is 500,000,000 shares, par value $.01 per share, of common stock.

FIFTH : The business and affairs of the Corporation shall be managed by or under the direction of the Board of Directors, which shall, prior to the Effective Time defined in and contemplated by the Agreement and Plan of Reorganization, dated as of June 5, 1992, between Entergy Corporation and Gulf States Utilities Company, as the same may be amended from time to time, consist of two (2) directors, and thereafter consist of not less than nine (9) nor more than nineteen (19) directors, the exact number of directors to be determined from time to time by resolution adopted by affirmative vote of a majority of the entire Board of Directors. A director shall hold office until the next succeeding annual meeting of stockholders and until his successor shall be elected, subject, however, to prior death, resignation, retirement or removal from office. Vacancies occurring in the Board of Directors and newly created directorships resulting from an increase in the authorized number of directors may be filled by a majority of the directors then in office, even if less than a quorum, or by a sole remaining director. Any director elected to fill a vacancy shall serve until the next succeeding annual meeting of stockholders and until his or her successor shall be elected and qualified.

SIXTH : In furtherance and not in limitation of the powers conferred by statute, the Board of Directors is expressly authorized to make, adopt, alter, amend, change or repeal the By-Laws of the Corporation. In addition to the powers and authority hereinbefore or by statute expressly conferred upon them, the directors are hereby empowered to exercise all such powers and do all such acts and things as may be exercised or done by the Corporation, subject, nevertheless, to the provisions of the statutes of Delaware, this Certificate of Incorporation, and any By-Laws adopted by the stockholders; provided, however , that no By-Laws hereafter adopted by the stockholders or otherwise shall invalidate any prior act of the directors which would have been valid if such By-Laws had not been adopted.

SEVENTH : Notwithstanding any other provision of this Certificate of Incorporation or the By-Laws of the Corporation to the contrary, no action required to be taken or which may be taken at any annual or special meeting of stockholders of the Corporation may be taken by written consent without such a meeting except any action taken upon the signing of a consent in writing by the holders of not less than the greater of (a) a majority of the outstanding stock of the Corporation entitled to vote thereon and (b) that number of shares of stock of the Corporation that would be required to take such action at a special or annual meeting of stockholders where holders of all outstanding stock of the Corporation were present, setting forth the action to be taken. Special meetings of stockholders of the Corporation may be called only by the Board of Directors, the Chairman of the Board, the person, if any, designated by the Board of Directors as the Chief Executive Officer of the Corporation, a majority of the members of the entire Executive Committee of the Board of Directors, if there shall be one, or by the holders of not less than a majority of the outstanding stock of the Corporation entitled to vote at the special meeting.

EIGHTH : A. To the fullest extent authorized or permitted by the General Corporation Law of the State of Delaware, as the same exists or may hereafter be amended, a director of the Corporation shall not be personally liable to the Corporation or its stockholders for monetary damages for breach of fiduciary duty as a director.

Any repeal or modification of this Section A of Article EIGHTH shall not have any effect on the liability or alleged liability of any director of this Corporation for any act or omission of such director occurring prior to such repeal or modification, or otherwise adversely affect any right or protection of a director of the Corporation existing at the time of such repeal or modification.

B. The Corporation shall indemnify its directors and officers to the fullest extent authorized or permitted by the General Corporation Law of the State of Delaware, as the same exists or may hereafter be amended, and such right to indemnification shall continue as to a person who has ceased to be a director or officer of the Corporation and shall inure to the benefit of his or her heirs, executors and administrators: provided, however, that, except for proceedings to enforce rights to indemnification, the Corporation shall not be obligated to indemnify any director or officer (or his or her heirs, executors or administrators) in connection with a proceeding (or part thereof) initiated by such person unless such proceeding (or part thereof) was authorized by the Board of Directors of the Corporation. The right to indemnification conferred in this Section B of Article EIGHTH shall include the right to be paid by the Corporation the expenses incurred in defending or otherwise participating in any proceeding in advance of its final disposition.

The Corporation may, to the extent authorized from time to time by the Board of Directors, provide rights to indemnification and to the advancement of expenses to employees and agents of the Corporation who are not directors or officers similar to those conferred in this Section B of Article EIGHTH to directors and officers of the Corporation.

The rights to indemnification and to the advancement of expenses conferred in this Section B of Article EIGHTH shall not be exclusive of any other right which any person may have or hereafter acquire under this Certificate of Incorporation, the By-Laws, any statute, agreement, vote of stockholders or disinterested directors, or otherwise.

Any repeal or modification of this Section B of Article EIGHTH by the stockholders of the Corporation shall not adversely affect any rights to indemnification and advancement of expenses of a director or officer of the Corporation existing pursuant to this Section B of Article EIGHTH with respect to any acts or omissions occurring prior to such repeal or modification.

C. The Corporation may maintain insurance, at its expense, to protect itself and any director, officer, employee or agent of the Corporation or another corporation, partnership, joint venture, trust, employee benefit plan or other enterprise against any expense, liability or loss, whether or not the Corporation would have the power to indemnify such person against such expense, liability or loss under the General Corporation Law of the State of Delaware. The Corporation may also obtain a letter of credit, act as self-insurer, create a reserve, trust, escrow, cash collateral or other fund or account, enter into indemnification agreements, pledge or grant a security interest in any assets or properties of the Corporation, or use any other mechanism or arrangement whatsoever in such amounts, at such costs, and upon such other terms and conditions as the Board of Directors shall deem appropriate for the protection of any or all such persons.

NINTH : Each of the directors of the Corporation may be removed from office at any time, with or without cause, by the affirmative vote of the holders of not less than a majority of the outstanding stock of the Corporation then entitled to vote for the election of such director.

TENTH : The name and mailing address of the Sole Incorporator is as follows:

Name                                      Mailing Address

Deborah M. Reusch             P.O. Box 636
                                               Wilmington, DE 19899

ELEVENTH: Meetings of stockholders may be held within or without the State of Delaware, as the By-Laws may provide. The books of the Corporation may be kept (subject to any provision contained in the General Corporation Law of the State of Delaware) outside the State of Delaware at such place or places as may be designated from time to time by the Board of Directors or in the By-Laws of the Corporation.

TWELFTH : The Corporation reserves the right to amend, alter, change or repeal any provision contained in this Certificate of Incorporation, in the manner now or hereafter prescribed by statute, and all rights conferred upon stockholders herein are granted subject to this reservation.

IN WITNESS WHEREOF, said Board of Directors has caused this Certificate to be signed by Robert D. Sloan, its Executive Vice President, General Counsel and Secretary this 10th day of October, 2006.

 

ENTERGY CORPORATION

 

By /s/ Robert D. Sloan
Name: Robert D. Sloan
Title: Executive Vice President, General
Counsel and Secretary

Attest:

 

 

By: /s/ Paul A. Castanon
Name: Paul A. Castanon
Title: Assistant Secretary

Exhibit 31(a)

CERTIFICATIONS

 

I, J. Wayne Leonard, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Entergy Corporation;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

 

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

 

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

 

/s/ J. Wayne Leonard
J. Wayne Leonard
Chairman and Chief Executive Officer
of Entergy Corporation

Date: November 8, 2006

Exhibit 31(b)

CERTIFICATIONS

 

I, Leo P. Denault, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Entergy Corporation;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

 

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

 

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

 

/s/ Leo P. Denault
Leo P. Denault
Executive Vice President and Chief Financial Officer of Entergy Corporation

Date: November 8, 2006

Exhibit 31(c)

CERTIFICATIONS

 

I, Hugh T. McDonald, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Entergy Arkansas, Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

 

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

 

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

 

/s/ Hugh T. McDonald
Hugh T. McDonald
Chairman, President, and Chief Executive Officer of
Entergy Arkansas, Inc.

Date: November 8, 2006

Exhibit 31(d)

CERTIFICATIONS

 

I, Jay A. Lewis, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Entergy Arkansas, Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

 

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

 

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Arkansas, Inc.

Date: November 8, 2006

Exhibit 31(e)

CERTIFICATIONS

 

I, Joseph F. Domino, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Entergy Gulf States, Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

 

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

 

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

 

/s/ Joseph F. Domino
Joseph F. Domino
Chairman, President and Chief Executive Officer-Texas
of Entergy Gulf States, Inc.

Date: November 8, 2006

Exhibit 31(f)

CERTIFICATIONS

 

I, E. Renae Conley, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Entergy Gulf States, Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

 

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

 

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ E. Renae Conley
E. Renae Conley
President and Chief Executive
Officer-Louisiana of Entergy Gulf States, Inc.

Date: November 8, 2006

Exhibit 31(g)

CERTIFICATIONS

 

I, Jay A. Lewis, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Entergy Gulf States, Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

 

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

 

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Gulf States, Inc.

Date: November 8, 2006

Exhibit 31(h)

CERTIFICATIONS

 

I, E. Renae Conley, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Entergy Louisiana, LLC;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

 

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

 

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

 

/s/ E. Renae Conley
E. Renae Conley
Chair of the Board, President, and Chief Executive Officer of
Entergy Louisiana, LLC

Date: November 8, 2006

Exhibit 31(i)

CERTIFICATIONS

 

I, Jay A. Lewis, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Entergy Louisiana, LLC;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

 

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

 

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Louisiana, LLC

Date: November 8, 2006

Exhibit 31(j)

CERTIFICATIONS

 

I, Carolyn C. Shanks, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Entergy Mississippi, Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

 

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

 

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

 

/s/ Carolyn Shanks
Carolyn C. Shanks
Chairman, President, and Chief Executive Officer of
Entergy Mississippi, Inc.

Date: November 8, 2006

Exhibit 31(k)

CERTIFICATIONS

 

I, Jay A. Lewis, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Entergy Mississippi, Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

 

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

 

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Mississippi, Inc.

Date: November 8, 2006

Exhibit 31(l)

CERTIFICATIONS

 

I, Daniel F. Packer, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Entergy New Orleans, Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

 

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

 

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

 

/s/ Daniel F. Packer
Daniel F. Packer
Chairman, President, and Chief Executive Officer of
Entergy New Orleans, Inc.

Date: November 8, 2006

Exhibit 31(m)

CERTIFICATIONS

 

I, Jay A. Lewis, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Entergy New Orleans, Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

 

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

 

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy New Orleans, Inc.

Date: November 8, 2006

Exhibit 31(n)

CERTIFICATIONS

 

I, Gary J. Taylor, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of System Energy Resources, Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

 

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

 

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

 

/s/ Gary J. Taylor
Gary J. Taylor
Chairman, President, and Chief Executive Officer of
System Energy Resources, Inc.

Date: November 8, 2006

Exhibit 31(o)

CERTIFICATIONS

 

I, Theodore H. Bunting, Jr., certify that:

1.

I have reviewed this quarterly report on Form 10-Q of System Energy Resources, Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

 

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

 

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

 

/s/ Theodore H. Bunting, Jr.
Theodore H. Bunting, Jr.
Vice President and Chief Financial Officer
of System Energy Resources, Inc.

Date: November 8, 2006

Exhibit 32(a)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

 

I, J. Wayne Leonard, Chief Executive Officer of Entergy Corporation (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)

The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2006 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

   

(2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

 

/s/ J. Wayne Leonard
J. Wayne Leonard
Chairman and Chief Executive Officer
of Entergy Corporation

Date: November 8, 2006

Exhibit 32(b)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

 

I, Leo P. Denault, Chief Financial Officer of Entergy Corporation (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)

The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2006 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

   

(2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

 

/s/ Leo P. Denault
Leo P. Denault
Executive Vice President and Chief Financial Officer of Entergy Corporation

Date: November 8, 2006

Exhibit 32(c)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

 

I, Hugh T. McDonald, Chairman, President and Chief Executive Officer of Entergy Arkansas, Inc. (the "Company") , certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)

The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2006 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

   

(2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

 

/s/ Hugh T .McDonald
Hugh T. McDonald
Chairman, President, and Chief Executive Officer
of Entergy Arkansas, Inc.

Date: November 8, 2006

Exhibit 32(d)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

 

I, Jay A. Lewis, Vice President and Chief Financial Officer of Entergy Arkansas, Inc. (the "Company") , certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)

The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2006 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

   

(2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

 

 

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Arkansas, Inc.

Date: November 8, 2006

Exhibit 32(e)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Joseph F. Domino, Chairman, President and Chief Executive Officer-Texas of Entergy Gulf States, Inc. (the "Company") , certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)

The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2006 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

   

(2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

 

/s/ Joseph F. Domino
Joseph F. Domino
Chairman, President and Chief Executive Officer-Texas of Entergy Gulf States, Inc.

Date: November 8, 2006

Exhibit 32(f)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, E. Renae Conley, President and Chief Executive Officer-Louisiana of Entergy Gulf States, Inc. (the "Company") , certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)

The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2006 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

   

(2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

 

/s/ E. Renae Conley
E. Renae Conley
President and Chief Executive Officer-Louisiana of
Entergy Gulf States, Inc.

Date: November 8, 2006

Exhibit 32(g)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Jay A. Lewis, Vice President and Chief Financial Officer of Entergy Gulf States, Inc. (the "Company") , certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)

The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2006 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

   

(2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

 

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Gulf States, Inc.

Date: November 8, 2006

Exhibit 32(h)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, E. Renae Conley, Chair of the Board, President and Chief Executive Officer of Entergy Louisiana, LLC (the "Company") , certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)

The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2006 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

   

(2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

 

/s/ E. Renae Conley
E. Renae Conley
Chair of the Board, President,
and Chief Executive Officer of Entergy Louisiana, LLC

Date: November 8, 2006

Exhibit 32(i)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Jay A. Lewis, Vice President and Chief Financial Officer of Entergy Louisiana, LLC (the "Company") , certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)

The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2006 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

   

(2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Louisiana, LLC

Date: November 8, 2006

Exhibit 32(j)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Carolyn C. Shanks, Chairman, President and Chief Executive Officer of Entergy Mississippi, Inc. (the "Company") , certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)

The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2006 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

   

(2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Carolyn C. Shanks
Carolyn C. Shanks
Chairman, President, and Chief Executive Officer of
Entergy Mississippi, Inc.

Date: November 8, 2006

Exhibit 32(k)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Jay A. Lewis, Vice President and Chief Financial Officer of Entergy Mississippi, Inc. (the "Company") , certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)

The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2006 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

   

(2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

 

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Mississippi, Inc.

Date: November 8, 2006

Exhibit 32(l)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Daniel F. Packer, Chairman, President and Chief Executive Officer of Entergy New Orleans, Inc. (the "Company") , certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)

The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2006 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

   

(2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Daniel F. Packer
Daniel F. Packer
Chairman, President, and Chief Executive Officer of
Entergy New Orleans, Inc.

Date: November 8, 2006

Exhibit 32(m)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Jay A. Lewis, Vice President and Chief Financial Officer of Entergy New Orleans, Inc. (the "Company") , certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)

The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2006 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

   

(2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy New Orleans, Inc.

Date: November 8, 2006

Exhibit 32(n)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Gary J. Taylor, Chairman, President and Chief Executive Officer of System Energy Resources, Inc. (the "Company") , certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)

The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2006 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

   

(2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Gary J. Taylor
Gary J. Taylor
Chairman, President, and Chief Executive Officer of
System Energy Resources, Inc.

Date: November 8, 2006

Exhibit 32(o)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Theodore H. Bunting, Jr., Chief Financial Officer of System Energy Resources, Inc. (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)

The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2006 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

   

(2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

 

/s/ Theodore H. Bunting, Jr.
Theodore H. Bunting, Jr.
Vice President and Chief Financial Officer
of System Energy Resources, Inc.

Date: November 8, 2006

           Exhibit 99(a)
             
Entergy Arkansas, Inc.
Computation of Ratios of Earnings to Fixed Charges and
Ratios of Earnings to Combined Fixed Charges and Preferred Dividends
             
  Twelve Months Ended
  December 31, Sept 30,
  2001 2002 2003 2004 2005 2006
             
Total Interest Charges $109,523 $103,210 $91,221 $84,430 $84,992 $81,320
Interest applicable to rentals 14,563 12,762 15,425 13,171 13,911 10,231
             
Total fixed charges, as defined 124,086 115,972 106,646 97,601 98,903 91,551
             
Preferred dividends, as defined (a) 12,348 11,869 14,274 12,646 12,093 10,125
             
Combined fixed charges and preferred dividends, as defined $136,434 $127,841 $120,920 $110,247 $110,996 $101,676
             
Earnings as defined:            
             
  Net Income $178,185 $135,643 $126,009 $142,210 $174,635 $175,516
  Add:            
   Provision for income taxes:            
      Total 105,933 71,404 105,296 89,064 96,949 38,602
    Fixed charges as above 124,086 115,972 106,646 97,601 98,903 91,551
             
Total earnings, as defined $408,204 $323,019 $337,951 $328,875 $370,487 $305,669
             
Ratio of earnings to fixed charges, as defined 3.29 2.79 3.17 3.37 3.75 3.34
             
Ratio of earnings to combined fixed charges and            
preferred dividends, as defined 2.99 2.53 2.79 2.98 3.34 3.01
             
             
------------------------            
(a) "Preferred dividends," as defined by SEC regulation S-K, are computed by dividing the preferred dividend requirement by one hundred percent (100%) minus the income tax rate.
             
          Exhibit 99(b)
             
Entergy Gulf States, Inc.
Computation of Ratios of Earnings to Fixed Charges and
Ratios of Earnings to Combined Fixed Charges and Preferred Dividends
         
  Twelve Months Ended
  December 31, Sept 30,
  2001 2002 2003 2004 2005 2006
             
Fixed charges, as defined:            
  Total Interest charges $174,368 $144,840 $157,343 $133,598 $126,788 $143,651
  Interest applicable to rentals 18,520 16,483 16,694 13,707 8,832 9,282
             
Total fixed charges, as defined 192,888 161,323 174,037 147,305 135,620 152,933
             
Preferred dividends, as defined (a) 13,017 6,190 6,845 6,991 6,444 6,313
             
Combined fixed charges and preferred dividends, as defined $205,905 $167,513 $180,882 $154,296 $142,064 $159,246
             
Earnings as defined:            
             
Income (loss) from continuing operations before extraordinary items and            
 the cumulative effect of accounting changes $179,444 $174,078 $63,895 $192,264 $206,497 $200,963
  Add:            
    Income Taxes 82,038 65,997 24,249 108,288 110,270 111,469
    Fixed charges as above 192,888 161,323 174,037 147,305 135,620 152,933
             
Total earnings, as defined (b) $454,370 $401,398 $262,181 $447,857 $452,387 $465,365
             
Ratio of earnings to fixed charges, as defined 2.36 2.49 1.51 3.04 3.34 3.04
             
Ratio of earnings to combined fixed charges and            
preferred dividends, as defined 2.21 2.40 1.45 2.90 3.18 2.92
             
(a) "Preferred dividends," as defined by SEC regulation S-K, are computed by dividing the preferred dividend requirement by one hundred percent (100%) minus the income tax rate.
             
             
           Exhibit 99(c)
             
Entergy Louisiana, LLC
Computation of Ratios of Earnings to Fixed Charges and
Ratios of Earnings to Combined Fixed Charges and Preferred Distributions
             
  Twelve Months Ended
  December 31, Sept 30,
  2001 2002 2003 2004 2005 2006
             
Fixed charges, as defined:            
Total Interest $116,076 $100,667 $76,756 $74,141 $85,418 $89,946
  Interest applicable to rentals 7,951 6,496 6,359 5,595 4,585 4,542
             
Total fixed charges, as defined 124,027 107,163 83,115 79,736 90,003 94,488
             
Preferred dividends, as defined (a) 0 0 0 0 0 8,544
             
Combined fixed charges and preferred dividends, as defined $124,027 $107,163 $83,115 $79,736 $90,003 $103,032
             
Earnings as defined:            
             
  Net Income $132,550 $144,709 $146,154 $127,495 $128,082 $136,440
  Add:            
    Provision for income taxes:            
Total Taxes 86,287 84,765 97,408 79,475 96,819 93,269
    Fixed charges as above 124,027 107,163 83,115 79,736 90,003 94,488
             
Total earnings, as defined $342,864 $336,637 $326,677 $286,706 $314,904 $324,197
             
Ratio of earnings to fixed charges, as defined 2.76 3.14 3.93 3.60 3.50 3.43
             
Ratio of earnings to combined fixed charges and            
 preferred dividends, as defined 2.76 3.14 3.93 3.60 3.50 3.15
             
             
             
(a) "Preferred dividends," as defined by SEC regulation S-K, are computed by dividing the preferred dividend requirement by one hundred percent (100%) minus the income tax rate.
             
             
            Exhibit 99(d)
             
Entergy Mississippi, Inc.
Computation of Ratios of Earnings to Fixed Charges and
Ratios of Earnings to Combined Fixed Charges and Preferred Dividends
             
  Twelve Months Ended
  December 31, Sept 30,
  2001 2002 2003 2004 2005 2006
             
Fixed charges, as defined:            
  Total Interest $50,991 $45,464 $47,464 $44,637 $43,707 $49,891
  Interest applicable to rentals 1,849 1,916 1,880 1,162 771 1,231
             
Total fixed charges, as defined 52,840 $47,380 $49,344 $45,799 $44,478 $51,122
             
Preferred dividends, as defined (a) 4,674 4,490 5,099 5,067 5,129 4,318
             
Combined fixed charges and preferred dividends, as defined $57,514 $51,870 $54,443 $50,866 $49,607 $55,440
             
Earnings as defined:            
             
  Net Income $39,620 $52,408 $67,058 $73,497 $62,103 $58,065
  Add:            
    Provision for income taxes:            
    Total income taxes 20,464 17,846 34,431 37,040 33,952 30,401
    Fixed charges as above 52,840 47,380 49,344 45,799 44,478 51,122
             
Total earnings, as defined $112,924 $117,634 $150,833 $156,336 $140,533 $139,588
             
Ratio of earnings to fixed charges, as defined 2.14 2.48 3.06 3.41 3.16 2.73
             
Ratio of earnings to combined fixed charges and            
 preferred dividends, as defined 1.96 2.27 2.77 3.07 2.83 2.52
             
             
------------------------            
(a) "Preferred dividends," as defined by SEC regulation S-K, are computed by dividing the preferred dividend requirement by one hundred percent (100%) minus the income tax rate.
             
          Exhibit 99(e)
             
Entergy New Orleans, Inc.
Computation of Ratios of Earnings to Fixed Charges and
Ratios of Earnings to Combined Fixed Charges and Preferred Dividends
             
  Twelve Months Ended
  December 31, Sept 30,
  2001 2002 2003 2004 2005 2006
             
Fixed charges, as defined:                
  Total Interest $19,661  $27,950  $17,786 $16,610 $13,555 $7,333
  Interest applicable to rentals 977   1,043  910 644 426 659
             
Total fixed charges, as defined 20,638  28,993  18,696 17,254 13,981 7,992
             
Preferred dividends, as defined (a) 2,898   2,736  1,686 1,545 1,172 663
             
Combined fixed charges and preferred dividends, as defined $23,536   $31,729   $20,382 $18,799 $15,153 $8,655
             
Earnings as defined:            
             
  Net Income ($2,195) ($230) $7,859 $28,072 $1,250 4,570
  Add:            
    Provision for income taxes:            
     Total (4,396) (422) 5,875 16,868 1,790 2,991
    Fixed charges as above 20,638   28,993   18,696 17,254 13,981 7,992
             
Total earnings, as defined $14,047  $28,341  $32,430 $62,194 $17,021 $15,553
             
Ratio of earnings to fixed charges, as defined 0.68   0.98   1.73 3.60 1.22 1.95
             
Ratio of earnings to combined fixed charges and            
 preferred dividends, as defined 0.60   0.89   1.59 3.31 1.12 1.80
             
             
------------------------            
(a) "Preferred dividends," as defined by SEC regulation S-K, are computed by dividing the preferred dividend requirement by one hundred percent (100%) minus the income tax rate.  
             
(b) For Entergy New Orleans, earnings for the twelve months ended December 31, 2001 were not adequate to cover fixed charges and combined fixed charges and preferred dividends by $6.6 million and $9.5 million, respectively.  
             
(c) For Entergy New Orleans, earnings for the twelve months ended December 31, 2002 were not adequate to cover combined fixed charges and preferred dividends by $0.7 million and $3.4 million, respectively.
            Exhibit 99(f)
             
System Energy Resources, Inc.
Computation of Ratios of Earnings to Fixed Charges and
Ratios of Earnings to Fixed Charges
         
  Twelve Months Ended
  December 31, Sept 30,
  2001 2002 2003 2004 2005 2006
             
Fixed charges, as defined:            
  Total Interest $138,018 $76,639 $64,620 $58,928 $60,424 $59,539
  Interest applicable to rentals 4,458 3,250 3,793 3,426 3,039 3,450
             
Total fixed charges, as defined $142,476 $79,889 $68,413 $62,354 $63,463 $62,989
             
Earnings as defined:            
  Net Income $116,355 $103,352 $106,003 $105,948 $111,644 119,620
  Add:            
    Provision for income taxes:            
      Total 43,761 76,177 75,845 78,013 69,343 73,261
    Fixed charges as above 142,476 79,889 68,413 62,354 63,463 62,989
             
Total earnings, as defined $302,592 $259,418 $250,261 $246,315 $244,450 $255,870
             
Ratio of earnings to fixed charges, as defined 2.12 3.25 3.66 3.95 3.85 4.06