ENTERGY TEXAS, INC. - Annual Report: 2008 (Form 10-K)

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

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

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

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

The aggregate market value of Entergy Corporation Common Stock, $0.01 Par Value, held by non-affiliates as of the end of the second quarter of 2008, was $23.0 billion based on the reported last sale price of $120.48 per share for such stock on the New York Stock Exchange on June 30, 2008. Entergy Corporation is the sole holder of the common stock of Entergy Arkansas, Inc., Entergy Mississippi, Inc., Entergy New Orleans, Inc., Entergy Texas, Inc., and System Energy Resources, Inc. Entergy Corporation is the sole holder of the common stock of Entergy Louisiana Holdings, Inc., which is the sole holder of the common membership interests in Entergy Louisiana, LLC. Entergy Corporation is the sole holder of the common stock of EGS Holdings, Inc., which is the sole holder of the common membership interests in Entergy Gulf States Louisiana, L.L.C.

Portions of the Proxy Statement of Entergy Corporation to be filed in connection with its Annual Meeting of Stockholders, to be held May 8, 2009, are incorporated by reference into Part III hereof.

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

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

• resolution of pending and future rate cases and negotiations, including various performance-based rate discussions and implementation of Texas restructuring legislation, and other regulatory proceedings, including those related to Entergy's System Agreement, Entergy's utility supply plan, recovery of storm costs, and recovery of fuel and purchased power costs
• changes in utility regulation, including the beginning or end of retail and wholesale competition, the ability to recover net utility assets and other potential stranded costs, the operations of the independent coordinator of transmission that includes Entergy's utility service territory, and the application of more stringent transmission reliability requirements or market power criteria by the FERC
• changes in regulation of nuclear generating facilities and nuclear materials and fuel, including possible shutdown of nuclear generating facilities, particularly those owned or operated by the Non-Utility Nuclear business
• resolution of pending or future applications for license extensions or modifications of nuclear generating facilities
• the performance of Entergy's generating plants, and particularly the capacity factors at its nuclear generating facilities
• Entergy's ability to develop and execute on a point of view regarding future prices of electricity, natural gas, and other energy-related commodities
• prices for power generated by Entergy's non-utility generating facilities, the ability to hedge, sell power forward or otherwise reduce the market price risk associated with those facilities, including the Non-Utility Nuclear plants, and the prices and availability of fuel and power Entergy must purchase for its utility customers, and Entergy's ability to meet credit support requirements for fuel and power supply contracts
• volatility and changes in markets for electricity, natural gas, uranium, and other energy-related commodities
• changes in law resulting from federal or state energy legislation
• changes in environmental, tax, and other laws, including requirements for reduced emissions of sulfur, nitrogen, carbon, mercury, and other substances
• uncertainty regarding the establishment of interim or permanent sites for spent nuclear fuel and nuclear waste storage and disposal
• variations in weather and the occurrence of hurricanes and other storms and disasters, including uncertainties associated with efforts to remediate the effects of hurricanes and ice storms (including most recently, Hurricane Gustav and Hurricane Ike and the January 2009 ice storm in Arkansas) and recovery of costs associated with restoration, including accessing funded storm reserves, federal and local cost recovery mechanisms, securitization, and insurance
• Entergy's ability to manage its capital projects and operation and maintenance costs
• Entergy's ability to purchase and sell assets at attractive prices and on other attractive terms

• the economic climate, and particularly growth in Entergy's Utility service territory and the Northeast United States
• the effects of Entergy's strategies to reduce tax payments
• changes in the financial markets, particularly those affecting the availability of capital and Entergy's ability to refinance existing debt, execute its share repurchase program, and fund investments and acquisitions
• actions of rating agencies, including changes in the ratings of debt and preferred stock, changes in general corporate ratings, and changes in the rating agencies' ratings criteria
• changes in inflation and interest rates
• the effect of litigation and government investigations or proceedings
• advances in technology
• the potential effects of threatened or actual terrorism and war
• Entergy's ability to attract and retain talented management and directors
• changes in accounting standards and corporate governance
• declines in the market prices of marketable securities and resulting funding requirements for Entergy's defined benefit pension and other postretirement benefit plans
• changes in the results of decommissioning trust fund earnings or in the timing of or cost to decommission nuclear plant sites
• the ability to successfully complete merger, acquisition, or divestiture plans, regulatory or other limitations imposed as a result of merger, acquisition, or divestiture, and the success of the business following a merger, acquisition, or divestiture
• and the risks inherent in the contemplated Non-Utility Nuclear spin-off, joint venture, and related transactions.  Entergy Corporation cannot provide any assurances that the spin-off or any of the proposed transactions related thereto will be completed, nor can it give assurances as to the terms on which such transactions will be consummated. The transaction is subject to certain conditions precedent, including regulatory approvals and the final approval by the Board.

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

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Entergy is an integrated energy company engaged primarily in electric power production and retail electric distribution operations. Entergy owns and operates power plants with approximately 30,000 MW of aggregate electric generating capacity, and Entergy is the second-largest nuclear power generator in the United States. Entergy delivers electricity to 2.7 million utility customers in Arkansas, Louisiana, Mississippi, and Texas. Entergy generated annual revenues of $13.1 billion in 2008 and had approximately 14,700 employees as of December 31, 2008.

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

• Utility generates, transmits, distributes, and sells electric power in a four-state service territory that includes portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operates a small natural gas distribution business.
• Non-Utility Nuclear owns and operates six nuclear power plants located in the northern United States and sells the electric power produced by those plants primarily to wholesale customers. This business also provides services to other nuclear power plant owners. As discussed further in "Management's Financial Discussion and Analysis," in November 2007, the Board approved a plan to pursue a separation of the Non-Utility Nuclear business from Entergy through a tax-free spin-off of Non-Utility Nuclear to Entergy shareholders.

In addition to its two primary, reportable, operating segments, Entergy also operates the non-nuclear wholesale assets business. The non-nuclear wholesale assets business sells to wholesale customers the electric power produced by power plants that it owns while it focuses on improving performance and exploring sales or restructuring opportunities for its power plants. Such opportunities are evaluated consistent with Entergy's market-based point-of-view.

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The following shows the principal subsidiaries and affiliates within Entergy's business segments. Companies that file reports and other information with the SEC under the Securities Exchange Act of 1934 are identified in bold-faced type.

Entergy aspires to achieve industry-leading total shareholder returns in an environmentally responsible fashion by leveraging the scale and expertise inherent in its core nuclear and utility operations.  Entergy's scope includes electricity generation, transmission and distribution as well as natural gas transportation and distribution.  Entergy focuses on operational excellence with an emphasis on safety, reliability, customer service, sustainability, cost efficiency, and risk management.  Entergy also focuses on portfolio management to make periodic buy, build, hold, or sell decisions based upon its analytically-derived points of view, which are updated as market conditions evolve.

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Entergy electronically files reports with the SEC, including annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, proxies, and amendments to such reports. The public may read and copy any materials that Entergy files with the SEC at the SEC's Public Reference Room at 100 F Street, N.E., Washington, D.C. 20549. The SEC also maintains an internet site that contains reports, proxy and information statements, and other information regarding registrants that file electronically with the SEC at http://www.sec.gov. Additionally, information about Entergy, including its reports filed with the SEC, is available without charge through its website, http://www.entergy.com, as soon as reasonably practicable after they are filed electronically with the SEC. Entergy is providing the address to its Internet site solely for the information of investors. Entergy does not intend the address to be an active link or to otherwise incorporate the contents of the website into this report.

Part I, Item 1 is continued on page 188.

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

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

• Utility generates, transmits, distributes, and sells electric power in a four-state service territory that includes portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operates a small natural gas distribution business.
• Non-Utility Nuclear owns and operates six nuclear power plants located in the northern United States and sells the electric power produced by those plants primarily to wholesale customers. This business also provides services to other nuclear power plant owners.

In addition to its two primary, reportable, operating segments, Entergy also operates the non-nuclear wholesale assets business. The non-nuclear wholesale assets business sells to wholesale customers the electric power produced by power plants that it owns while it focuses on improving performance and exploring sales or restructuring opportunities for its power plants. Such opportunities are evaluated consistent with Entergy's market-based point-of-view.

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

In November 2007, the Board approved a plan to pursue a separation of the Non-Utility Nuclear business from Entergy through a tax-free spin-off of the Non-Utility Nuclear business to Entergy shareholders. Upon completion of the Board-approved spin-off plan, Enexus Energy Corporation, a wholly-owned subsidiary of Entergy, would be a new, separate, and publicly-traded company. In addition, under the plan, Enexus and Entergy are expected to enter into a nuclear services business joint venture, EquaGen LLC, with 50% ownership by Enexus and 50% ownership by Entergy. The EquaGen board of managers would be comprised of equal membership from both Entergy and Enexus.

Under the Board-approved plan, the spin-off would result in Entergy Corporation's shareholders owning 100% of the common stock in both Enexus and Entergy. Also under the Board-approved plan, Enexus' business would be substantially comprised of Non-Utility Nuclear's assets, including its six nuclear power plants, and Non-Utility Nuclear's power marketing operation. Entergy Corporation's remaining business would primarily be comprised of the Utility business. EquaGen would operate the nuclear assets owned by Enexus under the Board-approved plan, and provide certain services to the Utility's nuclear operations. EquaGen would also be expected to offer nuclear services to third parties, including decommissioning, plant relicensing, plant operations, and ancillary services.

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Entergy Nuclear Operations, Inc., the current NRC-licensed operator of the Non-Utility Nuclear plants, filed an application in July 2007 with the NRC seeking indirect transfer of control of the operating licenses for the six Non-Utility Nuclear power plants, and supplemented that application in December 2007 to incorporate the planned business separation. Entergy Nuclear Operations, Inc., which is expected to be wholly-owned by EquaGen, would remain the operator of the plants after the separation.  Entergy Operations, Inc., the current NRC-licensed operator of Entergy's five Utility nuclear plants, would remain a wholly-owned subsidiary of Entergy and would continue to be the operator of the Utility nuclear plants. In the December 2007 supplement to the NRC application, Entergy Nuclear Operations, Inc. provided additional information regarding the spin-off transaction, organizational structure, technical and financial qualifications, and general corporate information. The NRC published a notice in the Federal Register establishing a period for the public to submit a request for hearing or petition to intervene in a hearing proceeding. The NRC notice period expired on February 5, 2008 and two petitions to intervene in the hearing proceeding were filed before the deadline. Each of the petitions opposes the NRC's approval of the license transfer on various grounds, including contentions that the approval request is not adequately supported regarding the basis for the proposed structure, the adequacy of decommissioning funding, and the adequacy of financial qualifications. Entergy submitted answers to the petitions on March 31 and April 8. On August 22, 2008, the NRC issued an order denying all of the petitions to intervene based upon the petitioners' failure to demonstrate the requisite standing to pursue their hearing requests. One of the petitioner groups filed a motion for reconsideration on September 4, 2008 and on September 15, 2008, Entergy filed a response opposing the motion for reconsideration. On September 23, 2008, the NRC issued an order denying the motion for reconsideration based upon several procedural errors.

Because resolution of any hearing requests is not a prerequisite to obtaining the required NRC approval, on July 28, 2008, the NRC staff approved the license transfers associated with the proposed new ownership structure of EquaGen, the proposed licensed operator, as well as the transfers to Enexus of the ownership of Big Rock Point, FitzPatrick, Indian Point Units 1, 2 and 3, Palisades, Pilgrim, and Vermont Yankee. The approval for the proposed new ownership structure is effective through July 28, 2009, and Entergy Nuclear Operations, Inc. can ask to extend the effective period. The review conducted by the NRC staff included matters such as the financial and technical qualifications of the new organizations, as well as decommissioning funding assurance. In connection with the NRC approvals, Enexus agreed to enter into a financial support agreement with the entities that own the nuclear power plants in the total amount of $700 million to provide financial support, if needed, for the operating costs of the six operating nuclear power plants.

Pursuant to Federal Power Act Section 203, on February 21, 2008, an application was filed with the FERC requesting approval for the indirect disposition and transfer of control of jurisdictional facilities of a public utility. In June 2008 the FERC issued an order authorizing the requested indirect disposition and transfer of control.

On January 28, 2008, Entergy Nuclear Vermont Yankee, LLC and Entergy Nuclear Operations, Inc. requested approval from the Vermont Public Service Board (VPSB) for the indirect transfer of control, consent to pledge assets, issue guarantees and assign material contracts, amendment to certificate of public good, and replacement of guaranty and substitution of a credit support agreement for Vermont Yankee. Several parties intervened in the proceeding. Discovery has been completed in this proceeding, in which parties could ask questions about or request the production of documents related to the transaction.

In addition, the Vermont Department of Public Service (VDPS), which is the public advocate in proceedings before the VPSB, prefiled its initial and rebuttal testimony in the case in which the VDPS takes the position that Entergy Nuclear Vermont Yankee and Entergy Nuclear Operations, Inc. have not demonstrated that the restructuring promotes the public good because its benefits do not outweigh the risks, raising concerns that the target rating for Enexus' debt is below investment grade and that the company may not have the financial capability to withstand adverse financial developments, such as an extended outage. The VDPS testimony also expresses concern about the EquaGen joint venture structure and Enexus' ability, under the operating agreement between Entergy Nuclear Vermont Yankee and Entergy Nuclear Operations, Inc., to ensure that Vermont Yankee is well-operated. Two distribution utilities that buy Vermont Yankee power prefiled testimony that also expresses concerns about the structure but found that there was a small net benefit to the restructuring. The VPSB conducted hearings on July 28-30, 2008, during which it considered the testimony prefiled by Entergy Nuclear Vermont Yankee, Entergy Nuclear Operations, Inc., the VDPS, and the two distribution utilities. Post-hearing briefing is complete and a decision from the VPSB is pending.

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On January 28, 2008, Entergy Nuclear FitzPatrick, LLC, Entergy Nuclear Indian Point 2, LLC, Entergy Nuclear Indian Point 3, LLC, and Entergy Nuclear Operations, Inc., and Enexus filed a petition with the New York Public Service Commission (NYPSC) requesting a declaratory ruling regarding corporate reorganization or in the alternative an order approving the transaction and an order approving debt financing. Petitioners also requested confirmation that the corporate reorganization will not have an effect on Entergy Nuclear FitzPatrick's, Entergy Nuclear Indian Point 2's, Entergy Nuclear Indian Point 3's, and Entergy Nuclear Operations, Inc.'s status as lightly regulated entities in New York, given that they will continue to be competitive wholesale generators. The New York State Attorney General's Office, Westchester County, and other intervenors have filed objections to the business separation and to the transfer of the FitzPatrick and Indian Point Energy Center nuclear power plants, arguing that the debt associated with the spin-off could threaten access to adequate financial resources for those nuclear power plants and because the New York State Attorney General's Office believes Entergy must file an environmental impact statement assessing the proposed corporate restructuring. In addition to the New York State Attorney General's Office, several other parties have also requested to be added to the service list for this proceeding.

On May 23, 2008, the NYPSC issued its Order Establishing Further Procedures in this matter. In the order, the NYPSC determined that due to the nuclear power plants' unique role in supporting the reliability of electric service in New York, and their large size and unique operational concerns, a more searching inquiry of the transaction will be conducted than if other types of lightly-regulated generation were at issue. Accordingly, the NYPSC assigned an ALJ to preside over this proceeding and prescribed a sixty (60) day discovery period. The order provided that after at least sixty (60) days, the ALJ would establish when the discovery period would conclude. The NYPSC stated that the scope of discovery will be tightly bounded by the public interest inquiry relevant to this proceeding; namely, adequacy and security of support for the decommissioning of the New York nuclear facilities; financial sufficiency of the proposed capital structure in supporting continued operation of the facilities; and, arrangements for managing, operating and maintaining the facilities. The NYPSC also stated that during the discovery period, the NYPSC Staff may conduct technical conferences to assist in the development of a full record in this proceeding.

On July 23, 2008, the ALJs issued a ruling concerning discovery and seeking comments on a proposed process and schedule. In the ruling, the ALJs proposed a process for completing a limited, prescribed discovery process, to be followed three weeks later by the filing of initial comments addressing defined issues, with reply comments due two weeks after the initial comment deadline. Following receipt of all comments, a ruling will be made on whether, and to what extent, an evidentiary hearing is required. The ALJs asked the parties to address three specific topic areas: (1) the financial impacts related to the specific issues previously outlined by the NYPSC; (2) other obligations associated with the arrangement for managing, operating and maintaining the facilities; and (3) the extent that New York Power Authority (NYPA) revenues from value sharing payments under the value sharing agreements between Entergy and NYPA would decrease. The ALJs have indicated that the potential financial effect of the termination of the value sharing payments on NYPA and New York electric consumers are factors the ALJs believe should be considered by the NYPSC in making its public interest determination.

In August 2008, Non-Utility Nuclear entered into a resolution of a dispute with NYPA over the applicability of the value sharing agreements to the FitzPatrick and Indian Point 3 nuclear power plants after the separation. Under the resolution, Non-Utility Nuclear agreed not to treat the separation as a "Cessation Event" that would terminate its obligation to make the payments under the value sharing agreements. As a result, after the separation, Enexus would continue to be obligated to make payments to NYPA due under the amended and restated value sharing agreements described above. For further discussion of the value sharing agreements, see Note 15 to the financial statements herein.

Entergy continues to seek regulatory approval from the NYPSC in a timely manner. On October 23, 2008, the ALJs issued notification to all parties that from their review of the submissions, all issues of fact and policy material to the relief requested by the petitioners have been

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thoroughly addressed by the parties, an adequate record for decision is available to the NYPSC, and no further formal proceedings are warranted. On December 11, 2008, notice was provided that the parties intended to conduct a settlement discussion which to date has not yielded an agreement. If the parties do not agree to a settlement, the ALJs will submit a recommendation to the NYPSC with respect to the transaction.

In connection with the separation, Enexus is currently expected to incur up to $4.5 billion of debt prior to completion of the separation. Currently, the debt is expected to be incurred in the following transactions:

• Enexus is expected to issue up to $3.0 billion of debt securities in partial consideration of Entergy's transfer to it of the Non-Utility Nuclear business.
• These debt securities are expected to be exchanged for up to $3.0 billion of debt securities that Entergy plans to issue prior to the separation. If the exchange occurs, the holders of the debt securities that Entergy plans to issue prior to the separation would become holders of up to $3.0 billion of Enexus debt securities.
• Enexus is expected to issue up to $1.5 billion of debt securities to third parties.

Out of the proceeds Enexus would receive from the issuance of debt securities to third parties, it expects to retain approximately $500 million, which it intends to use for working capital and other general corporate purposes. All of the remaining proceeds are expected to be transferred to Entergy to settle Enexus' intercompany indebtedness owed to Entergy, including indebtedness that Entergy will transfer to Enexus in the separation. Enexus will not receive any proceeds from either the issuance of the up to $3.0 billion of its debt securities or the exchange of its debt securities for Entergy debt securities. Entergy expects to use the proceeds that it receives from the issuance of its debt securities to reduce outstanding Entergy debt, repurchase Entergy common shares, or for other corporate purposes. The amount to be paid to Entergy, the amount and term of the debt Enexus would incur, and the type of debt and entity that would incur the debt have not been finally determined, but would be determined prior to the separation. A number of factors could affect this final determination, and the amount of debt ultimately incurred could be different from the amount disclosed.

Enexus executed a $1.175 billion credit facility in December 2008. Enexus is not permitted to draw on the $1.175 billion facility unless certain conditions are met on or prior to October 1, 2009, including consummation of the spin-off. Enexus may enter into other financing arrangements meant to support Enexus' working capital and general corporate needs and credit support obligations arising from hedging and normal course of business requirements.

Due to the condition of the financial markets, it is uncertain whether financing fundamental to the spin-off transaction can be effected in the near-term. Entergy and Enexus intend to launch the financing after requisite regulatory approvals are received and when market conditions are favorable for such an issuance. Entergy expects the transaction to qualify for tax-free treatment for U.S. federal income tax purposes for both Entergy and its shareholders, and Entergy has received a private letter ruling from the IRS regarding the tax free treatment. Final terms of the transactions and spin-off completion are subject to several conditions, including the final approval of the Board.

In September 2008, Hurricane Gustav and Hurricane Ike caused catastrophic damage to portions of Entergy's service territories in Louisiana and Texas, and to a lesser extent in Arkansas and Mississippi. The storms resulted in widespread power outages, significant damage to distribution, transmission, and generation infrastructure, and the loss of sales during the power outages. Total restoration costs for the repair and/or replacement of Entergy's electric facilities damaged by Hurricane Gustav and Hurricane Ike are estimated to be in the range of $1.295 billion to $1.360 billion, as follows:

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The Utility operating companies are considering all reasonable avenues to recover storm-related costs from Hurricane Gustav and Hurricane Ike, including, but not limited to, accessing funded storm reserves; federal and local cost recovery mechanisms, including requests for Community Development Block Grant funding; securitization; and insurance, to the extent deductibles are met. In October 2008, Entergy Gulf States Louisiana, Entergy Louisiana, and Entergy New Orleans drew a total of $229 million from their funded storm reserves. Entergy Arkansas requested and has received APSC approval for a surcharge to recover $22 million of its 2008 storm restoration costs, as discussed in Note 2 to the financial statements, and the other affected Utility operating companies expect to file for recovery of their storm restoration costs no later than the spring 2009. Entergy is currently evaluating the amount of the losses covered by insurance for Entergy and each of the affected Utility operating companies. Because most of the Hurricane Gustav damage was to distribution and transmission facilities that are generally not covered by property insurance, Entergy does not expect to meet its deductibles for that storm. Because Hurricane Ike caused more damage by flooding and also caused more damage to generation facilities as compared to Hurricane Gustav, it is more likely that Entergy will meet its deductibles for that storm.

Entergy has recorded the estimated costs incurred, including payments already made, that were necessary to return customers to service. Entergy has recorded approximately $746 million against its storm damage provisions or as regulatory assets and approximately $484 million in construction expenditures. Entergy recorded the regulatory assets in accordance with its accounting policies and based on the historic treatment of such costs in its service territories (except for Entergy Arkansas, which deferred $19 million of its costs pursuant to an APSC order, because it discontinued regulatory storm reserve accounting in July 2007 as a result of an earlier APSC order), because management believes that recovery through some form of regulatory mechanism is probable. Because Entergy has not gone through the regulatory process regarding these storm costs, however, there is an element of risk, and Entergy is unable to predict with certainty the degree of success it may have in its recovery initiatives, the amount of restoration costs that it may ultimately recover, or the timing of such recovery.

In January 2009 a severe ice storm caused significant damage to Entergy Arkansas' transmission and distribution lines, equipment, poles, and other facilities. The preliminary cost estimate for the damage caused by the ice storm is approximately $165 million to $200 million, of which approximately $80 million to $100 million is estimated to be operating and maintenance type costs and the remainder is estimated to be capital investment. On January 30, 2009, the APSC issued an order inviting and encouraging electric public utilities to file specific proposals for the recovery of extraordinary storm restoration expenses associated with the ice storm. Although Entergy Arkansas has not yet filed a proposal for the recovery of its costs, on February 16, 2009, it did file a request with the APSC requesting an accounting order authorizing deferral of the operating and maintenance cost portion of Entergy Arkansas' ice storm restoration costs pending their recovery.

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As a result of the effects of Hurricane Katrina and the effect of extensive flooding that resulted from levee breaks in and around the New Orleans area, on September 23, 2005, Entergy New Orleans filed a voluntary petition in bankruptcy court seeking reorganization relief under Chapter 11 of the U.S. Bankruptcy Code. On May 7, 2007, the bankruptcy judge entered an order confirming Entergy New Orleans' plan of reorganization. With the receipt of CDBG funds, and the agreement on insurance recovery with one of its excess insurers, Entergy New Orleans waived the conditions precedent in its plan of reorganization, and the plan became effective on May 8, 2007. See Note 18 to the financial statements for additional discussion of Entergy New Orleans' bankruptcy proceedings.

With confirmation of the plan of reorganization, Entergy reconsolidated Entergy New Orleans in the second quarter 2007, retroactive to January 1, 2007. Because Entergy owns all of the common stock of Entergy New Orleans, reconsolidation does not affect the amount of net income that Entergy recorded from Entergy New Orleans' operations for the current or prior periods, but does result in Entergy New Orleans' financial results being included in each individual income statement line item in 2007, rather than only its net income being presented as "Equity in earnings of unconsolidated equity affiliates," as remains the case for 2006.

Following are income statement variances for Utility, Non-Utility Nuclear, Parent & Other business segments, and Entergy comparing 2008 to 2007 showing how much the line item increased or (decreased) in comparison to the prior period:

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

Earnings were negatively affected in the fourth quarter 2007 by expenses of $52 million ($32 million net-of-tax) recorded in connection with a nuclear operations fleet alignment. This process was undertaken with the goals of eliminating redundancies, capturing economies of scale, and

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clearly establishing organizational governance. Most of the expenses related to the voluntary severance program offered to employees. Approximately 200 employees from the Non-Utility Nuclear business and 150 employees in the Utility business accepted the voluntary severance program offers.

Utility

Following is an analysis of the change in net revenue comparing 2008 to 2007.

The purchased power capacity variance is primarily due to higher capacity charges. A portion of the variance 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.

The volume/weather variance is primarily due to the effect of less favorable weather compared to the same period in 2007 and decreased electricity usage primarily during the unbilled sales period. Hurricane Gustav and Hurricane Ike, which hit the Utility's service territories in September 2008, contributed an estimated $46 million to the decrease in electricity usage. Industrial sales were also depressed by the continuing effects of the hurricanes and, especially in the latter part of the year, because of the overall decline of the economy, leading to lower usage in the latter part of the year affecting both the large customer industrial segment as well as small and mid-sized industrial customers. The decreases in electricity usage were partially offset by an increase in residential and commercial customer electricity usage that occurred during the periods of the year not affected by the hurricanes.

• an increase in the Attala power plant costs recovered through the power management rider by Entergy Mississippi. The net income effect of this recovery is limited to a portion representing an allowed return on equity with the remainder offset by Attala power plant costs in other operation and maintenance expenses, depreciation expenses, and taxes other than income taxes;
• a storm damage rider that became effective in October 2007 at Entergy Mississippi; and
• an Energy Efficiency rider that became effective in November 2007 at Entergy Arkansas.

The establishment of the storm damage rider and the Energy Efficiency rider results in an increase in rider revenue and a corresponding increase in other operation and maintenance expense with no impact on net income. The retail electric price variance was partially offset by:

• the absence of interim storm recoveries through the formula rate plans at Entergy Louisiana and Entergy Gulf States Louisiana which ceased upon the Act 55 financing of storm costs in the third quarter 2008; and
• a credit passed on to customers as a result of the Act 55 storm cost financings.

Refer to "Liquidity and Capital Resources - Hurricane Katrina and Hurricane Rita" below and Note 2 to the financial statements for a discussion of the interim recovery of storm costs and the Act 55 storm cost financings.

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Non-Utility Nuclear

Following is an analysis of the change in net revenue comparing 2008 to 2007.

As shown in the table above, net revenue for Non-Utility Nuclear increased by $495 million, or 27%, in 2008 compared to 2007 primarily due to higher pricing in its contracts to sell power, additional production available from the acquisition of Palisades in April 2007, and fewer outage days. In addition to the refueling outages shown in the table below, 2007 was affected by a 28 day unplanned outage. Included in the Palisades net revenue is $76 million and $50 million of amortization of the Palisades purchased power agreement in 2008 and 2007, respectively, which is non-cash revenue and is discussed in Note 15 to the financial statements. Following are key performance measures for 2008 and 2007:

When Non-Utility Nuclear acquired its six nuclear power plants it also entered into purchased power agreements with each of the sellers. For four of the plants, the 688 MW Pilgrim, 838 MW FitzPatrick, 1,028 MW Indian Point 2, and 1,041 MW Indian Point 3 plants, the original purchased power agreements with the sellers expired in 2004. The purchased power agreement with the seller of the 605 MW Vermont Yankee plant extends into 2012, and the purchased power agreement with the seller of the 798 MW Palisades plant extends into 2022. Market prices in the New York and New England power markets, where the four plants with original purchased power agreements that expired in 2004 are located, increased since the purchase of these plants, and the contracts that Non-Utility Nuclear entered into after the original contracts expired, as well as realized day ahead and spot market sales, have generally been at higher prices than the original contracts. Non-Utility Nuclear's annual average realized price per MWh increased from $39.40 for 2003 to $59.51 for 2008. In addition, as shown in the contracted sale of energy table in "Market and Credit Risk Sensitive Instruments," Non-Utility Nuclear has sold forward 86% of its

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planned energy output for 2009 for an average contracted energy price of $61 per MWh. Power prices increased in the period from 2003 through 2008 primarily because of increases in the price of natural gas. Natural gas prices increased in the period from 2003 through 2008 primarily because of rising production costs and limited imports of liquefied natural gas, both caused by global demand and increases in the price of crude oil. In addition, increases in the price of power during this period were caused secondarily by rising heat rates, which in turn were caused primarily by load growth outpacing new unit additions. The majority of the existing long-term contracts for power from these four plants expire by the end of 2011. Recent trends in the energy commodity markets have resulted in lower natural gas prices and consequently current prevailing market prices for electricity in the New York and New England power regions are generally below the prices in Non-Utility Nuclear's existing contracts in those regions. Therefore, it is uncertain whether Non-Utility Nuclear will continue to experience increases in its annual realized price per MWh.

Utility

Other operation and maintenance expenses increased from $1,856 million for 2007 to $1,867 million for 2008. The variance includes:

• the write-off in the fourth quarter 2008 of $52 million of costs previously accumulated in Entergy Arkansas's storm reserve and $16 million of removal costs associated with the termination of a lease, both in connection with the December 2008 Arkansas Court of Appeals decision in Entergy Arkansas's base rate case.  The base rate case is discussed in more detail in Note 2 to the financial statements;
• a decrease of $39 million in payroll-related and benefits costs;
• a decrease of $21 million related to expenses recorded in 2007 in connection with the nuclear operations fleet alignment, as discussed above;
• a decrease of approximately $23 million as a result of the deferral or capitalization of storm restoration costs for Hurricane Gustav and Hurricane Ike, which hit the Utility's service territories in September 2008;
• an increase of $18 million in storm damage charges as a result of several storms hitting Entergy Arkansas' service territory in 2008, including Hurricane Gustav and Hurricane Ike in the third quarter 2008. Entergy Arkansas discontinued regulatory storm reserve accounting beginning July 2007 as a result of the APSC order issued in Entergy Arkansas' base rate case. As a result, non-capital storm expenses of $41 million were charged in 2008 to other operation and maintenance expenses. In December 2008, $19 million of these storm expenses were deferred per an APSC order and will be recovered through revenues in 2009. See Note 2 to the financial statements for discussion of the APSC order; and
• an increase of $17 million in fossil plant expenses due to the Ouachita plant acquisition in 2008.

Depreciation and amortization expenses increased primarily due to:

• a revision in the third quarter 2007 related to depreciation on storm cost-related assets. Recoveries of the costs of those assets are now through the Act 55 financing of storm costs, as approved by the LPSC in the third quarter 2007. See "Liquidity and Capital Resources - Hurricane Katrina and Hurricane Rita" below and Note 2 to the financial statements for a discussion of the Act 55 storm cost financing;
• a revision in the fourth quarter 2008 of estimated depreciable lives involving certain intangible assets in accordance with formula rate plan treatment; and
• an increase in plant in service.

Other income increased primarily due to dividends earned of $29.5 million by Entergy Louisiana and $10.3 million by Entergy Gulf States Louisiana on investments in preferred membership interests of Entergy Holdings Company. This increase was substantially offset by the cessation of carrying charges on storm restoration costs as a result of the Act 55 storm cost financing in 2007 and lower interest earned on the decommissioning trust funds. The dividends on preferred stock are eliminated in consolidation and have no effect on net income since the investment is in another Entergy subsidiary.

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Non-Utility Nuclear

Other operation and maintenance expenses increased from $760 million in 2007 to $773 million in 2008. This increase was primarily due to deferring costs for amortization from three refueling outages in 2008 compared to four refueling outages in 2007 and to a $34 million increase associated with owning the Palisades plant, which was acquired in April 2007, for the entire period. The increase was partially offset by a decrease of $29 million related to expenses recorded in 2007 in connection with the nuclear operations fleet alignment, as discussed above.

Depreciation and amortization expenses increased from $99 million in 2007 to $126 million in 2008 as a result of the acquisition of Palisades in April 2007, which contributed $12 million to the increase, as well as other increases in plant in service.

Other income decreased primarily due to $50 million in charges to interest income in 2008 resulting from the recognition of impairments of certain securities held in Non-Utility Nuclear's decommissioning trust funds that are not considered temporary.

Other expenses increased due to increases of $23 million in nuclear refueling outage expenses and $15 million in decommissioning expenses that primarily resulted from the acquisition of Palisades in April 2007.

Parent & Other

Other operation and maintenance expenses increased for the parent company, Entergy Corporation, primarily due to outside services costs of $69 million related to the planned spin-off of the Non-Utility Nuclear business.

Interest charges decreased primarily due to lower interest rates on borrowings under Entergy Corporation's revolving credit facility.

Other income decreased primarily due to the elimination for consolidation purposes of dividends earned of $29.5 million by Entergy Louisiana and $10.3 million by Entergy Gulf States Louisiana on investments in preferred membership interests of Entergy Holdings Company, as discussed above.

The effective income tax rate for 2008 was 32.7%. The reduction in the effective income tax rate versus the federal statutory rate of 35% in 2008 is primarily due to:

• a capital loss recognized for income tax purposes on the liquidation of Entergy Power Generation, LLC in the third quarter 2008, which resulted in an income tax benefit of approximately $79.5 million. Entergy Power Generation, LLC was a holding company in Entergy's non-nuclear wholesale assets business;
• recognition of tax benefits of $44.3 million associated with the loss on sale of stock of Entergy Asset Management, Inc., a non-nuclear wholesale subsidiary, as a result of a settlement with the IRS; and
• an adjustment to state income taxes for Non-Utility Nuclear to reflect the effect of a change in the methodology of computing Massachusetts state income taxes resulting from legislation passed in the third quarter 2008, which resulted in an income tax benefit of approximately $18.8 million.

These factors were partially offset by:

• income taxes recorded by Entergy Power Generation, LLC, prior to its liquidation, resulting from the redemption payments it received in connection with its investment in Entergy Nuclear Power Marketing, LLC during the third quarter 2008, which resulted in an income tax expense of approximately $16.1 million; and
• book and tax differences for utility plant items and state income taxes at the Utility operating companies, including the flow-through treatment of Arkansas write-offs discussed above.

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The effective income tax rate for 2007 was 30.7%. The reduction in the effective income tax rate versus the federal statutory rate of 35% in 2007 is primarily due to:

• a reduction in income tax expense due to a step-up in the tax basis on the Indian Point 2 non-qualified decommissioning trust fund resulting from restructuring of the trusts, which reduced deferred taxes on the trust fund and reduced current tax expense;
• the resolution of tax audit issues involving the 2002-2003 audit cycle;
• an adjustment to state income taxes for Non-Utility Nuclear to reflect the effect of a change in the methodology of computing New York state income taxes as required by that state's taxing authority;
• book and tax differences related to the allowance for equity funds used during construction; and
• the amortization of investment tax credits.

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

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

Following are income statement variances for Utility, Non-Utility Nuclear, Parent & Other business segments, and Entergy comparing 2007 to 2006 showing how much the line item increased or (decreased) in comparison to the prior period: