Entergy - 10-Q quarterly report FY

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DEFINITIONS (Continued)

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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. 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.

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See the Form 10-K for a discussion of the Entergy New Orleans bankruptcy proceeding. Following is an update to the discussion in the Form 10-K. In April 2006, the bankruptcy judge extended the exclusivity period for filing a plan of reorganization by Entergy New Orleans to August 21, 2006. Entergy New Orleans has filed another motion to extend the exclusivity period for filing its plan of reorganization, requesting that the deadline be extended an additional 120 days until December 19, 2006. The court entered an order extending the August 21, 2006 date for Entergy New Orleans' exclusive right to file a plan of reorganization until the court can hear and rule on Entergy New Orleans' motion to extend, which was set for hearing on September 18, 2006. In order to file a plan of reorganization no later than December 2006, Entergy New Orleans believes that it needs resolution of its June 2006 formula rate plan and storm rider filings and commitme nt on timing and amount of CDBG funds. If the motion to extend is granted, Entergy New Orleans will have the exclusive right to file its plan of reorganization until December 19, 2006, and will have until February 15, 2007 to obtain acceptances of its plan by each class of impaired creditors.

In addition, the bankruptcy judge had set a date of April 19, 2006 by which creditors with prepetition claims against Entergy New Orleans must, with certain exceptions, file their proofs of claim in the bankruptcy case. Approximately 500 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.

Since the filing of the bankruptcy proceedings, Entergy New Orleans has 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 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. En tergy New Orleans declared and paid the dividend due on July 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.

Municipalization is one potential outcome of Entergy New Orleans' recovery effort. In June 2006 Louisiana passed a law that establishes a governance structure for a public power authority, if municipalization of Entergy New Orleans' utility business is pursued.

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

Second Quarter 2006 Compared to Second Quarter 2005

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

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 second quarter of 2006 to the second quarter of 2005.

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Six Months Ended June 30, 2006 Compared to Six Months Ended June 30, 2005

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

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 six months ended June 30, 2006 to the six months ended June 30, 2005.

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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 June 30, 2006, Entergy New Orleans had approximately $40 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, including August 23, 2006. Entergy 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 this amendment is subject to bankruptcy court approval. Entergy New Orleans has filed a motion with the bankruptcy court to authorize Entergy New Orleans to enter into the amendment, which is set for hearing August 16, 2006.

Capital Structure

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

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

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 is an update 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. 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 an additional approximately $100 million of the trust fund to Consumers Energy depending upon a pending tax ruling. Also as pa rt 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 first quarter 2007, pending the approvals of the NRC, the FERC, the Michigan Public Service Commission, and other regulatory agencies.

Cash Flow Activity

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

Operating Activities

Entergy's cash flow provided by operating activities increased by $707 million for the six months ended June 30, 2006 compared to the six months ended June 30, 2005 primarily due to the following activity:

• Utility provided $1,088 million in cash from operating activities in 2006 compared to providing $539 million in 2005 primarily due to the receipt of an income tax refund (discussed below), increased collection of deferred fuel costs, and the effect in 2005 of a $90 million refund paid to customers in Louisiana, partially offset by storm restoration spending.
• Non-Utility Nuclear provided $473 million in cash from operating activities in 2006 compared to providing $235 million in 2005 primarily due to an increase of $130 million in income tax refunds received and an increase in net revenue.
• Parent & Other used $81 million in cash from operating activities in 2006 compared to using $1 million in 2005 primarily due to an increase in cash used of $72 million in the non-nuclear wholesale assets business primarily due to an increase in taxes paid and interest payments.

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.

Investing Activities

Net cash used in investing activities increased by $380 million for the six months ended June 30, 2006 compared to the six months ended June 30, 2005 primarily due to the following activity:

• Entergy Mississippi purchased the 480 MW Attala power plant in January 2006 for $88 million.

The increase was partially offset by:

• Entergy's investment in other temporary investments increased by $188 million during the six months ended June 30, 2005. Entergy had no activity in other temporary investments during the six months ended June 30, 2006.
• Entergy Louisiana purchased the 718 MW Perryville power plant in June 2005 for $162 million.
• The proceeds from the sale of the retail electric portion of the Competitive Retail Services business operating in the ERCOT region of Texas and the sale of the non-nuclear wholesale asset business' remaining interest in a power development project.

Financing Activities

Net cash used in financing activities increased by $175 million for the six months ended June 30, 2006 compared to the six months ended June 30, 2005. Following is a description of the significant financing activity occurring during the first six months of 2006 and 2005:

• Entergy Louisiana Holdings, Inc. redeemed all $100.5 million of its outstanding preferred stock in June 2006.
• Entergy Corporation increased the net borrowings on its credit facilities by $20 million during the six months ended June 30, 2006 compared to $585 million during the six months ended June 30, 2005. See Note 4 to the consolidated financial statements for a description of the Entergy Corporation credit facilities.
• Entergy Corporation repurchased $640 million of its common stock during the six months ended June 30, 2005.

See Note 4 to the consolidated financial statements for the details of long-term debt activity in the six months ended June 30, 2006.

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

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 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 coal 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 does 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.

Entergy Arkansas filed for rehearing of the APSC's orders, asking that the energy cost rate filed in March 2006 be implemented in May 2006 subject to refund, asserting that the APSC did not follow appropriate procedures in suspending the operation of the energy cost recovery rider, and asking the APSC to rescind its show cause order. On May 8, 2006 the APSC denied Entergy Arkansas' requests for rehearing. Entergy Arkansas appealed the APSC's decision, but later filed a motion to dismiss the appeal following the APSC's decision described below.

In June 2006, Entergy Arkansas once again filed a motion with the APSC seeking 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.

A hearing in the APSC energy cost recovery investigation is scheduled for October 2006.

On June 7, 2006, Entergy Arkansas filed the cost of service study ordered by the APSC. On that date Entergy Arkansas also filed notice with the APSC that it intends to file for a change in base rates within 60 to 90 days of its notice. Entergy Arkansas expects to make that filing in August 2006.

See "System Agreement Litigation" 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 plans to propose 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 or a production cost allocation 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 $744 thousand to capacity deferrals. The refund liability pertained to the periods 2004-2005 as well as the interim period in which a $37.8 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. The filing shows that Entergy Gulf States' return on equity was within the allowed bandwidth. The filing also indicates that under the formula rate plan rider for approved capacity additions, a $7.1 million rate increase is required to recover LPSC-approved incremental

deferred and ongoing capacity requirements. The filing is subject to a period of LPSC Staff review, and rate changes associated with the formula rate plan are scheduled to take effect 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 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. The filing shows that Entergy Louisiana's return on equity was within the allowed bandwidth. The filing also indicates that under the formula rate plan rider for approved capacity additions, a $121 million rate increase is required to recover LPSC-approved incremental deferred and ongoing capacity requirements. Entergy Louisiana requested recovery of the capacity deferrals over a three-year period, including carrying charges. $51 million of the rate increase is associated with these deferrals. The remaining $70 million of the rate increase is associated with ongoing capacity costs. The filing is subject to a period of LPSC Staff review, and rate changes associated with the formula rate plan are scheduled to take effect with the first billing cycle of September 2006.

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 will be 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 show 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 (a portion of Grand Gulf costs was previously recovered through base rates). Under that alternative, annual increases of $6.4 million in electric base rate revenues (an increase of 4.4%) and $22.8 million in gas base rate revenues (an increase of 160.9%) are warranted. The filings triggered the prescribed four-month period for review by the City Council's Advisors and other parties, and rate adjustments, if any, could be implemented as soon as the first billing cycle of November 2006.

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 seeks to recover over a ten-year period the $114 million in electric restoration costs and the $25 million in gas restoration costs that it has 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 seeks to establish over a ten-year period a $150 million storm reserve to provide for the risk of another storm. Entergy New Orleans requested that the City Council consider the proposed riders within the same time frame as the formula rate plans, which would allow implementation as soon as the first billing cycle of November 2006.

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 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 utilit y 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 various parties submitting initial and reply briefs between August and November 2006. 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 operating utilities whose total production costs are farthest above the Entergy System average. For purposes of the Entergy Arkansas rate filings discussed above in "State and Local Rate Regulation" that are expected to be made in mid-August 2006, an assessment of the potential effects of the FERC's June 2005 order, as amended by its December 2005 order on rehearing, has been calculated on the basis of a 2006 test year, using a 2006 gas price that consists of a non-weighted average of twelve months of gas prices calculated as follows: January through May 2006 are actual, volume-weighted monthly averages of day-ahead cash prices as reported by Energy Intelligence Natural Gas Week; the June 2006 price is the First of the Month Index price as reported by Platts Inside FERC's Gas Market Report; the July 2006 price is the 5/31/06 NYMEX Henry Hub settlement price; and August through December 2006 are 30 calendar - -day rolling averages as of May 31, 2006 of forward NYMEX Henry Hub gas contracts.  For example the August 2006 price is 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 is 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:

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.

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.

On July 31, 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. Based on well-established 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.

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 area s: 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 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.

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 have filed requests for rehearing of the FERC order, and those requests are still pending.

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.

Entergy made its compliance filing with the FERC on May 24, 2006, including the executed ICT agreement with SPP. Entergy informed the FERC that, assuming it has received all required approvals, Entergy intends to install SPP as the ICT within 30 days of FERC approval of the ICT agreement. Several parties have filed protests regarding Entergy's compliance filing, and consideration of Entergy's compliance filing is pending at the FERC.

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

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 two quarters of the year):

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.

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.

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 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 June 30, 2006, based on power prices at that time, Entergy had in place as collateral $1,275 million of Entergy Corporation guarantees for wholesale transactions, including $100 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 $445 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 two quarters of the year):

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.

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.

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