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.

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 "believes," "intends," "plans," "predicts" and "estimates" and similar expressions are intended to identify forward-looking statements but are not the only means to identify these statements. Although each of these registrants believes that these forward-looking statements and the underlying assumptions are reasonable, it cannot provide assurance that they will prove correct. Any forward-looking statement is based on information current as of the date of this combined report and speaks only as of the date on which such statement is made. Except to the extent required by the federal securities laws, these registrants undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events, or otherwise.

Forward-looking statements involve a number of risks and uncertainties. There are factors that could cause actual results to differ materially from those expressed or implied in the forward-looking statements, including those factors discussed or incorporated by reference in (a) Item 1A. Risk Factors in the Form 10-K, (b) Management's Financial Discussion and Analysis in the Form 10-K and in this report, and (c) the following factors (in addition to others described elsewhere in this combined report and in subsequent securities filings):

• resolution of pending and future rate cases and negotiations, including various performance-based rate discussions and implementation of Texas 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
• Entergy's and its subsidiaries' ability to manage their operation and maintenance 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 implementation of the independent coordinator of transmission that includes Entergy's utility service territory, and the application of market power criteria by the FERC
• the economic climate, and particularly growth in Entergy's service territory
• variations in weather and the occurrence of hurricanes and other storms and disasters, including uncertainties associated with efforts to remediate the effects of Hurricanes Katrina and Rita and recovery of costs associated with restoration including Entergy's ability to obtain financial assistance from governmental authorities in connection with these storms
• the outcome of the Chapter 11 bankruptcy proceeding of Entergy New Orleans, and the impact of this proceeding on other Entergy companies
• the performance of Entergy's generating plants, and particularly the capacity factors at its nuclear generating facilities
• 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
• Entergy's ability to develop and execute on a point of view regarding future prices of electricity, natural gas, and other energy-related commodities
• Entergy's ability to purchase and sell assets at attractive prices and on other attractive terms
• prices for power generated by Entergy's unregulated 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 regulation of nuclear generating facilities and nuclear materials and fuel, including possible shutdown of nuclear generating facilities, particularly those in the Non-Utility Nuclear business
• uncertainty regarding the establishment of interim or permanent sites for spent nuclear fuel storage and disposal

• resolution of pending or future applications for license extensions or modifications of nuclear generating facilities
• changes in law resulting from federal energy legislation, including the effects of PUHCA repeal
• changes in environmental, tax, and other laws, including requirements for reduced emissions of sulfur, nitrogen, carbon, mercury, and other substances
• advances in technology
• the potential effects of threatened or actual terrorism and war
• the effects of Entergy's strategies to reduce tax payments
• the effects of litigation and government investigations
• changes in accounting standards and corporate governance
• Entergy's ability to attract and retain talented management and directors

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DEFINITIONS (Continued)

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DEFINITIONS (Concluded)

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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.

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.

Entergy has reached an agreement with one of its excess insurers under which Entergy will receive $69.5 million in settlement of its Hurricane Katrina claim. Entergy expects that $53.7 million of this amount will be allocated to Entergy New Orleans. Entergy New Orleans submitted the agreement to the bankruptcy court, which approved the agreement on April 25, 2007. Entergy expects to receive the proceeds under the settlement agreement by the end of May 2007.

See the Form 10-K for a discussion of the Katrina Relief Bill, a hurricane aid package that includes $11.5 billion in Community Development Block Grants (for the states affected by Hurricanes Katrina, Rita, and Wilma) that allows state and local leaders to fund individual recovery priorities.

In March 2007, the City Council certified that Entergy New Orleans has incurred $205 million in storm-related costs through December 2006 that are eligible for CDBG funding under the state action plan, and certified Entergy New Orleans' estimated costs of $465 million for the gas system rebuild. In April 2007, Entergy New Orleans executed an agreement with the Louisiana Office of Community Development under which $200 million of CDBG funds will be made available to Entergy New Orleans. Entergy New Orleans submitted the agreement to the bankruptcy court, which approved it on April 25, 2007. Entergy New Orleans received $171.7 million of the funds on April 27, 2007, and the remainder will be paid to Entergy New Orleans as it incurs and submits additional eligible costs.

See the Form 10-K for a discussion of the Entergy New Orleans bankruptcy proceeding. 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.

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Following are significant terms in Entergy New Orleans' plan of reorganization:

• Entergy New Orleans will pay in full, in cash, within 15 days of the effective date, the allowed third-party prepetition accounts payable (estimated at $29.5 million).
• Entergy New Orleans will issue notes due in three years in satisfaction of its affiliate prepetition accounts payable (estimated at $69.5 million), including its indebtedness to the Entergy System money pool.
• `Entergy New Orleans will also pay interest from September 23, 2005 on the third-party and affiliate accounts payable at the Louisiana judicial rate of interest in 2005 (6%) and 2006 (8%), and at the Louisiana judicial rate of interest plus 1% thereafter. The Louisiana judicial rate of interest is 9.5% for 2007.
• Entergy New Orleans will repay to Entergy Corporation, in full, in cash, within 15 days of the effective date, the outstanding borrowings under the debtor-in-possession (DIP) credit agreement. On May 8, 2007, Entergy New Orleans had $67 million of outstanding borrowings under the DIP credit agreement.
• Entergy New Orleans' first mortgage bonds will remain outstanding with their current maturity dates and interest terms. Pursuant to an agreement with the first mortgage bondholders, Entergy New Orleans will pay, on the effective date, the first mortgage bondholders an amount equal to the one year of interest from the bankruptcy petition date that the bondholders had waived previously in the bankruptcy proceeding.
• Entergy New Orleans' preferred stock will remain outstanding on its current dividend terms, with payment, within 15 days of the effective date, of unpaid preferred dividends in arrears.
• Litigation claims will generally be unaltered, and will generally proceed as if Entergy New Orleans had not filed for bankruptcy protection, with exceptions for certain claims.

Entergy New Orleans currently estimates that the prepetition claims that will be allowed and paid (either in cash or by notes) in the bankruptcy case will approximate the prepetition liabilities currently recorded by Entergy New Orleans, including interest.

With confirmation of the plan of reorganization, Entergy expects to reconsolidate 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 will not affect the amount of net income that Entergy records from Entergy New Orleans' operations for any current or prior period, but will result in Entergy New Orleans' results being included in each individual income statement line item in 2007, rather than just its net income being presented as "Equity in earnings (loss) of unconsolidated equity affiliates," as will remain the case for 2005 and 2006.

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

Following is an analysis of the change in net revenue comparing the first quarter of 2007 to the first quarter of 2006.

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The base revenues variance resulted from rate increases primarily at Entergy Louisiana effective September 2006 for the 2005 formula rate plan filing to recover LPSC-approved incremental deferred and ongoing purchased power capacity costs and for the interim recovery of storm costs. The formula rate plan filing is discussed in Note 2 to the financial statements in the Form 10-K.

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 net wholesale revenue variance is primarily due to decreased results from wholesale contracts and lower wholesale prices.

The fuel recovery variance resulted primarily from adjustments of fuel clause recoveries in the first quarter of 2006 in Entergy Gulf States' Louisiana jurisdiction and a reserve for potential rate refunds in the first quarter of 2007 in Entergy Gulf States' Texas jurisdiction as a result of a PUCT ruling related to the application of past PUCT rulings addressing transition to competition in Texas.

The purchased power capacity variance is due to higher capacity charges and new purchased power contracts that began in mid-2006. 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 at Entergy Louisiana, as discussed above.

Net revenue increased for Non-Utility Nuclear primarily due to higher pricing in its contracts to sell power, partially offset by reduced production as a result of a refueling outage in the first quarter of 2007. There were no refueling outages in the first quarter of 2006. Following are key performance measures for Non-Utility Nuclear for the first quarters of 2007 and 2006:

Net revenue decreased for Parent & Other primarily due to lower production as a result of an additional plant outage in the first quarter 2007 compared to the same period in 2006.

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Other operation and maintenance expenses increased from $359 million for the first quarter of 2006 to $385 million for the first quarter of 2007 primarily due to:

• an increase of $9 million in transmission expenses, including transmission system maintenance, independent coordinator of transmission expenses, and loss reserves;
• an increase of $7 million in distribution expenses, including higher labor and contract costs and the timing of vegetation maintenance costs compared to 2006;
• an increase of $5 million as a result of higher insurance premiums due to amending coverage in mid-2006 in addition to the timing of premium payments compared to 2006;
• an increase of $3 million in nuclear outage preparation costs and higher NRC fees; and
• an increase of $3 million in legal services fees.

Other operation and maintenance expenses decreased from $20 million for the first quarter of 2006 to $9 million for the first quarter of 2007 primarily due to restoration expenses at the Harrison County plant incurred in the first quarter of 2006.

Depreciation and amortization expenses increased from $186 million for the first quarter of 2006 to $203 million for the first quarter of 2007 primarily due to an increase in plant in service.

Other income increased from $43 million for the first quarter of 2006 to $53 million for the first quarter of 2007 primarily due to carrying charges on storm costs.

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

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Entergy's capitalization is balanced between equity and debt, as shown in the following table. The increase in the debt to capital percentage from 2006 to 2007 is the result of additional borrowings under Entergy Corporation's revolving credit facilities, along with a decrease in shareholders' equity primarily due to repurchases of common stock.

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 Corporation also has the ability to issue letters of credit against the total borrowing capacity of both the three-year and the five-year credit facilities. Following is a summary of the borrowings outstanding and capacity available under these facilities as of March 31, 2007:

See Note 4 to the financial statements for additional discussion of Entergy's credit facilities, and see Part II, Item 5 for an update of the borrowings outstanding as of May 8, 2007.

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 2007 through 2009.

In April 2007, Entergy's Non-Utility Nuclear business purchased the 798 MW Palisades nuclear energy plant located near South Haven, Michigan from Consumers Energy Company for a cash payment of $380 million. Entergy received the plant, nuclear fuel, inventories, and other assets. The liability to decommission the plant, as well as related decommissioning trust funds of approximately $250 million, was also transferred to Entergy's Non-Utility Nuclear business. Entergy's Non-Utility Nuclear business executed a unit contingent, 15-year purchased power agreement (PPA) with Consumers Energy for 100% of the plant's output, excluding any future uprates. Prices under the PPA range from $43.50/MWh in 2007 to $61.50/MWh in 2022, and the average price under the PPA is $51/MWh. In the first quarter 2007, the NRC renewed Palisades' operating license until 2031. Also as part of the transaction, Consumers Energy paid Entergy's Non-Utility Nuclear business $30 million to assume responsibility for spent fuel at the decommissioned Big Rock Point nuclear plant, which is located near Charlevoix, Michigan.

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In April 2007, Entergy Louisiana announced that it plans to pursue the self-build solid fuel repowering of a 538MW unit at its Little Gypsy plant.  Petroleum coke will be the unit's primary fuel source.  Entergy Louisiana expects to spend $1.02 billion on the project, and expects the project to be completed in 2011-2012. The planned capital investment estimate in the Form 10-K included the capital required for a project of this type.

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. As of March 31, 2007, Entergy New Orleans had $42 million of outstanding borrowings under the DIP credit agreement. During April 2007, at the same time that it made a scheduled pension plan contribution, Entergy New Orleans borrowed under the DIP credit agreement, and on May 8, 2007 had $67 million of outstanding borrowings under the DIP credit agreement.

As shown in Entergy's Statements of Cash Flows, cash flows for the three months ended March 31, 2007 and 2006 were as follows:

Entergy's cash flow provided by operating activities decreased by $536 million for the three months ended March 31, 2007 compared to the three months ended March 31, 2006. Following are cash flows from operating activities by segment:

• Utility provided $318 million in cash from operating activities in 2007 compared to providing $483 million in 2006, primarily due to decreased collection of fuel costs and the catch-up in receivable collections in 2006 due to delays caused by the hurricanes in 2005, partially offset by pension funding and storm restoration spending in 2006.
• Non-Utility Nuclear provided $216 million in cash from operating activities in 2007 compared to providing $213 million in 2006.
• Parent & Other used $58 million in cash from operating activities in 2007 compared to providing $316 million in 2006, primarily due to receipt of a $344 million income tax refund in 2006. The income tax refund was received by Entergy Corporation (including $71 million attributable to Entergy New Orleans) as a result of net operating loss carry back provisions contained in the Gulf Opportunity Zone Act of 2005. In accordance with Entergy's intercompany tax allocation agreement, $273 million of the refund was distributed to the Utility business in April 2006, with most of the remainder distributed to Non-Utility Nuclear.

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Net cash used in investing activities decreased by $606 million for the three months ended March 31, 2007 compared to the three months ended March 31, 2006 primarily due to the following activity:

• Construction expenditures were $379 million lower in 2007 than in 2006, primarily due to storm restoration expenditures in the Utility business in 2006.
• Entergy Mississippi realized proceeds in 2007 from $100 million of investments held in trust that were received from a bond issuance in 2006 and used to redeem bonds in 2007.
• The purchase of the 480 MW Attala power plant by Entergy Mississippi in January 2006.

Financing activities used $159 million of cash for the three months ended March 31, 2007 compared to providing $16 million of cash for the three months ended March 31, 2006 primarily due to the following activity:

• Entergy Mississippi redeemed $100 million of first mortgage bonds in 2007 and issued $100 million of first mortgage bonds in 2006.
• Entergy Corporation repurchased $558 million of its common stock in the first quarter 2007, and did not repurchase any shares of its common stock in the first quarter 2006.
• Entergy Arkansas issued $75 million of preferred stock in March 2006.

This activity was offset by Entergy Corporation increasing the net borrowings under its credit facilities by $615 million in the first quarter 2007, compared to increasing the net borrowings under its credit facilities by $20 million in the first quarter 2006. See Note 4 to the financial statements for a description of the Entergy Corporation credit facilities.

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

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

During March and April 2007, the Utility operating companies made four separate filings with the FERC proposing modifications to the formula used to calculate the rough production cost equalization payments/receipts.  The proposed modifications will (1) continue to reflect in the calculation the results of the Utility operating companies' gas hedging program for boiler fuel; (2) confirm the allocation of an individual Utility operating company's bandwidth payment/receipt to its wholesale loads, if any, and establish the allocation between retail jurisdictions in the case of Entergy Louisiana and Entergy Gulf States that provide retail service to customers in two separate jurisdictions; (3) modify the basis for functionalizing certain categories of costs among the Utility operating companies to be consistent with other service schedules in the System Agreement; and (4) properly reflect in the calculation property under capital lease.  The Utility operating companies have requested that all four

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filings be allowed to become effective no later than May 29, 2007 so that they can be reflected in the calculation of the first payments/receipts.  The APSC, LPSC, MPSC, City Council, and the AEEC have each intervened and in some instances protested one or more of these four filings. Separately, on April 3, 2007, the LPSC filed a complaint with the FERC in which it seeks to have the FERC order the following modifications to the rough production costs equalization calculation: (1) elimination of interruptible loads from the methodology used to allocate demand-related capacity costs; and (2) change of the method used to re-price energy from the Vidalia hydroelectric project for purposes of calculating production cost disparities. Entergy has filed an intervention and protest in this proceeding.

In conjunction with the recent application of Entergy Gulf States and Calcasieu Power, LLC seeking FERC approval of Entergy Gulf States' acquisition of the Calcasieu Generating Facility, the Utility operating companies filed a Petition for Declaratory Order requesting that the FERC find either (1) that in those circumstances where a resource to be acquired or constructed has been determined by Entergy's Operating Committee to be a resource devoted to serving Entergy System load and has been approved by the applicable retail regulator, the cost of such resource shall be reflected in the production cost disparity calculation; or (2) that Entergy Gulf States' acquisition of the Calcasieu facility is prudent and the costs are properly reflected in the production cost disparity calculation.  The APSC, LPSC, MPSC, City Council, NRG, Occidental, LEUG, AEEC, and EPSA have intervened in the proceeding, with the APSC, LPSC, and City Council filing protests.

On April 3, 2007, the U.S. Court of Appeals for the D.C. Circuit issued its opinion in the LPSC's appeal of the FERC's March 2004 and April 2005 orders related to the treatment under the System Agreement of the Utility operating companies' interruptible loads.  In its opinion, the D.C. Circuit concluded that the FERC (1) acted arbitrarily and capriciously by allowing the Utility operating companies to phase-in the effects of the elimination of the interruptible load over a 12-month period of time; (2) failed to adequately explain why refunds could not be ordered under Section 206(c) of the Federal Power Act; and (3) exercised appropriately its discretion to defer addressing the cost of sulfur dioxide allowances until a later time.  The D.C. Circuit remanded the matter to the FERC for a more considered determination on the issue of refunds.

On April 27, 2007, the FERC denied the requests for rehearing filed regarding the Utility operating companies' compliance filing to implement the System Agreement decision, with one exception regarding the issue of retrospective refunds. That issue will be addressed subsequent to the remanded proceeding involving the interruptible load decision discussed in the previous paragraph.

As discussed in the Form 10-K, in the FERC's April 2006 order approving Entergy's ICT proposal, the FERC stated that the weekly procurement process (WPP) must be operational within approximately 14 months of the FERC order, or June 24, 2007, or the FERC may reevaluate all approvals to proceed with the ICT.  The Utility operating companies have been working with the ICT and a software vendor to develop the software and systems necessary to implement the WPP and currently expect that the WPP will commence operations on June 18, 2007.  The software and systems are still being developed and tested, however.  Entergy will notify the FERC as soon as practicable if it and the ICT determine that the June 24, 2007 deadline for implementing the WPP cannot be met. The Utility operating companies also filed with the FERC on April 24, 2007 a request to make certain corrections and limited modifications to the current WPP tariff provisions and requested that the FERC allow these proposed changes to go into effect no later than June 18, 2007.  Additionally, Entergy Gulf States and Entergy Louisiana are required to file with the LPSC a compliance filing for review of the model to be used in the WPP prior to receiving final approval for implementation of the WPP.  The Utility operating companies currently expect to submit the required compliance filing during May 2007.

In accordance with the provisions of the FERC order approving the ICT, during the first quarter 2007 the Utility operating companies notified the FERC, the ICT, and the stakeholders that certain instances had been identified in which software errors related to the AFC process had resulted in the reporting of inaccurate data.  Following the reporting of the initial errors, certain market participants urged the FERC to move forward with

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the AFC hearing process in light of those errors.  In April 2007, the FERC issued an order terminating the AFC hearing, now that Entergy's ICT has been installed. Requests for rehearing of the FERC order canceling the AFC hearing are due in May 2007.

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, unless otherwise contracted, is subject to the variability of market power prices. Following is an updated summary of the amount of the Non-Utility Nuclear business' output that is sold forward as of March 31, 2007 under physical or financial contracts (2007 represents the remaining three quarters of the year):

The Vermont Yankee acquisition included a 10-year PPA under which the former owners will buy the power produced by the plant through the expiration in 2012 of the current operating license for the plant. The PPA includes an adjustment clause under which the prices specified in the PPA will be adjusted downward monthly if power market prices drop below PPA prices, which has not happened thus far and is not expected in the foreseeable future.

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. Non-Utility Nuclear calculated that nothing was owed to NYPA under the value sharing agreements for 2005. On November 1, 2006, NYPA filed a demand for arbitration claiming that $90.5 million was due to NYPA under these agreements for 2005. Non-Utility Nuclear filed a motion in New York state court to determine whether NYPA's claim should be decided by a court as opposed to an arbitrator. In February 2007, the court issued an order denying Non-Utility Nuclear's request, and NYPA's claim is now in binding arbitration. Non-Utility Nuclear has also calculated that nothing was owed to NYPA under the value sharing agreements for 2006. On April 24, 2007, NYPA filed an amended demand for arbitration claiming that an additional $54 million was due to NYPA under the value sharing agreements for 2006. With respect to both of these claims, Non-Utility Nuclear disagrees with NYPA's interpretation of the value sharing agreements, believes it has meritorious defenses to NYPA's claims, and intends to defend against those claims vigorously.

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 is 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 form of

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collateral to satisfy these requirements is an Entergy Corporation guaranty.  Cash and letters of credit are also acceptable forms of collateral.  At March 31, 2007, based on power prices at that time, Entergy had in place as collateral $797 million of Entergy Corporation guarantees for wholesale transactions, including $73 million of guarantees that support letters of credit. The assurance requirement associated with Non-Utility Nuclear is estimated to increase by an amount of up to $297 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 as of March 31, 2007 (2007 represents the remaining three quarters of the year):

As of March 31, 2007, approximately 98% of Non-Utility Nuclear's counterparty exposure from energy and capacity contracts is with counterparties with investment grade credit ratings.

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.

The FASB issued Statement of Financial Accounting Standards No. 159, "The Fair Value Option for Financial Assets and Financial Liabilities" (SFAS 159) during the first quarter of 2007. SFAS 159 provides an option for companies to select certain financial assets and liabilities to be accounted for at fair value with changes in the fair value of those assets or liabilities being reported through earnings. The intent of the standard is to mitigate volatility in reported earnings caused by the application of the more complicated fair value hedging accounting rules. Under SFAS 159, companies can select existing assets or liabilities for this fair value option concurrent with the effective date of January 1, 2008 for companies with fiscal years ending December 31 or can select future assets or liabilities as they are acquired or entered into. Entergy is in the process of evaluating the potential effect of making this accounting election.

In June 2006, the EITF reached a consensus on EITF Issue 06-3 "How Taxes Collected from Customers and Remitted to Governmental Authorities Should Be Presented in the Income Statement (That Is, Gross versus Net Presentation)" (EITF 06-3). The scope of this issue includes any tax assessed by a governmental authority that is both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, and may include, but is not limited to, sales, use, value added, and some excise taxes. Under EITF 06-3, the presentation of taxes within the scope of this issue on either a gross basis (included in revenues and costs) or a net basis (excluded from revenues) basis is an

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accounting policy decision that should be disclosed. For any such taxes reported on a gross basis, the amounts of those taxes in interim and annual financial statements, for each period for which an income statement is presented, should be disclosed if those amounts are significant. Entergy's policy is to present such taxes on a net basis. EITF 06-3 did not affect Entergy's financial statements.

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