10-Q

__________________________________________________________________________________________

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

FORM 10-Q

(Mark One)
X	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the Quarterly Period Ended June 30, 2008
	OR
	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the transition period from ____________ to ____________

Commission File Number	Registrant, State of Incorporation, Address of Principal Executive Offices, Telephone Number, and IRS Employer Identification No.	Commission File Number	Registrant, State of Incorporation, Address of Principal Executive Offices, Telephone Number, and IRS Employer Identification No.
1-11299	ENTERGY CORPORATION (a Delaware corporation) 639 Loyola Avenue New Orleans, Louisiana 70113 Telephone (504) 576-4000 72-1229752	1-31508	ENTERGY MISSISSIPPI, INC. (a Mississippi corporation) 308 East Pearl Street Jackson, Mississippi 39201 Telephone (601) 368-5000 64-0205830
1-10764	ENTERGY ARKANSAS, INC. (an Arkansas corporation) 425 West Capitol Avenue Little Rock, Arkansas 72201 Telephone (501) 377-4000 71-0005900	0-5807	ENTERGY NEW ORLEANS, INC. (a Louisiana corporation) 1600 Perdido Street, Building 505 New Orleans, Louisiana 70112 Telephone (504) 670-3700 72-0273040
333-148557	ENTERGY GULF STATES LOUISIANA, L.L.C. (a Louisiana limited liability company) 446 North Boulevard Baton Rouge, Louisiana 70802 Telephone (800) 368-3749 74-0662730	000-53134	ENTERGY TEXAS, INC. (a Texas corporation) 350 Pine Street Beaumont, Texas 77701 Telephone (409) 838-6631 61-1435798
1-32718	ENTERGY LOUISIANA, LLC (a Texas limited liability company) 446 North Boulevard Baton Rouge, Louisiana 70802 Telephone (225) 381-5868 75-3206126	1-9067	SYSTEM ENERGY RESOURCES, INC. (an Arkansas corporation) Echelon One 1340 Echelon Parkway Jackson, Mississippi 39213 Telephone (601) 368-5000 72-0752777

__________________________________________________________________________________________

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

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

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

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

Common Stock Outstanding		Outstanding at July 31, 2008
Entergy Corporation	($0.01 par value)	191,574,567

Entergy Corporation, Entergy Arkansas, Inc., Entergy Gulf States Louisiana, L.L.C., Entergy Louisiana, LLC, Entergy Mississippi, Inc., Entergy New Orleans, Inc., Entergy Texas, Inc., and System Energy Resources, Inc. separately file this combined Quarterly Report on Form 10-Q. Information contained herein relating to any individual company is filed by such company on its own behalf. Each company reports herein only as to itself and makes no other representations whatsoever as to any other company. This combined Quarterly Report on Form 10-Q supplements and updates the Entergy Annual Report on Form 10-K for the calendar year ended December 31, 2007, the Entergy Texas Form 10, and the Entergy and Entergy Texas Quarterly Reports on Form 10-Q for the quarter ended March 31, 2008, filed by the individual registrants with the SEC, and should be read in conjunction therewith.

ENTERGY CORPORATION AND SUBSIDIARIES
INDEX TO QUARTERLY REPORT ON FORM 10-Q
June 30, 2008

			Page Number
Definitions			1
Entergy Corporation and Subsidiaries
	Management's Financial Discussion and Analysis
		Plan to Pursue Separation of Non-Utility Nuclear	3
		Results of Operations	6
		Liquidity and Capital Resources	11
		Significant Factors and Known Trends	16
		Critical Accounting Estimates	20
		New Accounting Pronouncements	20
	Consolidated Statements of Income		21
	Consolidated Statements of Cash Flows		22
	Consolidated Balance Sheets		24
	Consolidated Statements of Retained Earnings, Comprehensive Income, and Paid-In Capital		26
	Selected Operating Results		28
Notes to Financial Statements			29
Part I. Item 4. Controls and Procedures			51
Entergy Arkansas, Inc.
	Management's Financial Discussion and Analysis
		Results of Operations	53
		Liquidity and Capital Resources	56
		Significant Factors and Known Trends	58
		Critical Accounting Estimates	59
		New Accounting Pronouncements	59
	Income Statements		60
	Statements of Cash Flows		61
	Balance Sheets		62
	Selected Operating Results		64
Entergy Gulf States Louisiana, L.L.C.
	Management's Financial Discussion and Analysis
		Jurisdictional Separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas	65
		Results of Operations	65
		Liquidity and Capital Resources	70
		Significant Factors and Known Trends	72
		Critical Accounting Estimates	73
		New Accounting Pronouncements	73
	Income Statements		74
	Statements of Cash Flows		75
	Balance Sheets		76
	Statements of Members' Equity and Comprehensive Income		78
	Selected Operating Results		79
Entergy Louisiana, LLC
	Management's Financial Discussion and Analysis
		Results of Operations	80
		Liquidity and Capital Resources	82
		Significant Factors and Known Trends	85
		Critical Accounting Estimates	87
		New Accounting Pronouncements	87
	Income Statements		88
	Statements of Cash Flows		89

ENTERGY CORPORATION AND SUBSIDIARIES
INDEX TO QUARTERLY REPORT ON FORM 10-Q
June 30, 2008

			Page Number
	Balance Sheets		90
	Statements of Members' Equity and Comprehensive Income		92
	Selected Operating Results		93
Entergy Mississippi, Inc.
	Management's Financial Discussion and Analysis
		Results of Operations	94
		Liquidity and Capital Resources	97
		Significant Factors and Known Trends	98
		Critical Accounting Estimates	99
		New Accounting Pronouncements	99
	Income Statements		100
	Statements of Cash Flows		101
	Balance Sheets		102
	Selected Operating Results		104
Entergy New Orleans, Inc.
	Management's Financial Discussion and Analysis
		Hurricane Katrina	105
		Results of Operations	105
		Liquidity and Capital Resources	108
		Significant Factors and Known Trends	109
		Critical Accounting Estimates	110
		New Accounting Pronouncements	110
	Income Statements		111
	Statements of Cash Flows		113
	Balance Sheets		114
	Selected Operating Results		116
Entergy Texas, Inc.
	Management's Financial Discussion and Analysis
		Jurisdictional Separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas	117
		Results of Operations	117
		Liquidity and Capital Resources	120
		Significant Factors and Known Trends	122
		Critical Accounting Estimates	123
		New Accounting Pronouncements	123
	Consolidated Statements of Operations		124
	Consolidated Statements of Cash Flows		125
	Consolidated Balance Sheets		126
	Consolidated Statements of Retained Earnings and Paid-in-Capital		128
	Selected Operating Results		129
System Energy Resources, Inc.
	Management's Financial Discussion and Analysis
		Results of Operations	130
		Liquidity and Capital Resources	130
		Significant Factors and Known Trends	131
		Critical Accounting Estimates	132
		New Accounting Pronouncements	132
	Income Statements		133
	Statements of Cash Flows		135
	Balance Sheets		136

ENTERGY CORPORATION AND SUBSIDIARIES
INDEX TO QUARTERLY REPORT ON FORM 10-Q
June 30, 2008

		Page Number
Part II. Other Information
	Item 1. Legal Proceedings	138
	Item 1A. Risk Factors	138
	Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	138
	Item 4. Submission of Matters to a Vote of Security Holders	139
	Item 5. Other Information	140
	Item 6. Exhibits	145
Signature		148

FORWARD-LOOKING INFORMATION

In this combined report and from time to time, Entergy Corporation and the Registrant Subsidiaries each makes statements as a registrant concerning its expectations, beliefs, plans, objectives, goals, strategies, and future events or performance. Such statements are "forward-looking statements" within the meaning of the Private Securities Litigation Reform Act of 1995. Words such as "believes," "intends," "plans," "predicts," "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 and the Entergy Texas Form 10, (b) Management's Financial Discussion and Analysis in the Form 10-K, the Entergy Texas Form 10, 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 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 in the Non-Utility Nuclear business
• resolution of pending or future applications for license renewals 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 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 law resulting from federal 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 Katrina and Rita and recovery of costs associated with restoration
• Entergy's and its subsidiaries' ability to manage their 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 service territory
• the effects of Entergy's strategies to reduce tax payments

FORWARD-LOOKING INFORMATION (Concluded)

• 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
• 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
• and the following transactional factors (in addition to others described elsewhere in this and in subsequent securities filings): (i) risks inherent in the contemplated Non-Utility Nuclear spin-off, joint venture and related transactions (including the level of debt incurred by the spun-off company and the terms and costs related thereto); (ii) legislative and regulatory actions; and (iii) conditions of the capital markets during the periods covered by the forward-looking statements.  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.

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DEFINITIONS

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

Abbreviation or Acronym	Term
AEEC	Arkansas Electric Energy Consumers
AFUDC	Allowance for Funds Used During Construction
ALJ	Administrative Law Judge
ANO 1 and 2	Units 1 and 2 of Arkansas Nuclear One Steam Electric Generating Station (nuclear), owned by Entergy Arkansas
APSC	Arkansas Public Service Commission
Board	Board of Directors of Entergy Corporation
capacity factor	Actual plant output divided by maximum potential plant output for the period
City Council or Council	Council of the City of New Orleans, Louisiana
Entergy	Entergy Corporation and its direct and indirect subsidiaries
Entergy Corporation	Entergy Corporation, a Delaware corporation
Entergy Gulf States, Inc.	Predecessor company for financial reporting purposes to Entergy Gulf States Louisiana that included the assets and business operations of both Entergy Gulf States Louisiana and Entergy Texas
Entergy Gulf States Louisiana	Entergy Gulf States Louisiana, L.L.C., a company created in connection with the jurisdictional separation of Entergy Gulf States, Inc. and the successor company to Entergy Gulf States, Inc. for financial reporting purposes. The term is also used to refer to the Louisiana jurisdictional business of Entergy Gulf States, Inc., as the context requires.
Entergy-Koch	Entergy-Koch, LP, a joint venture equally owned by subsidiaries of Entergy and Koch Industries, Inc.
Entergy Texas	Entergy Texas, Inc., a company created in connection with the jurisdictional separation of Entergy Gulf States, Inc. The term is also used to refer to the Texas jurisdictional business of Entergy Gulf States, Inc., as the context requires.
Entergy Texas Form 10	Registration Statement on Form 10 filed with the SEC by Entergy Texas, as amended July 15, 2008.
EPA	United States Environmental Protection Agency
ERCOT	Electric Reliability Council of Texas
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
firm liquidated damages	Transaction that requires receipt or delivery of energy at a specified delivery point (usually at a market hub not associated with a specific asset); if a party fails to deliver or receive energy, the defaulting party must compensate the other party as specified in the contract
Form 10-K	Annual Report on Form 10-K for the calendar year ended December 31, 2007 filed by Entergy Corporation and its Registrant Subsidiaries (other than Entergy Texas) with the SEC
Grand Gulf	Unit No. 1 of Grand Gulf Steam Electric Generating Station (nuclear), 90% owned or leased by System Energy
GWh	Gigawatt-hour(s), which equals one million kilowatt-hours
Independence	Independence Steam Electric Station (coal), owned 16% by Entergy Arkansas, 25% by Entergy Mississippi, and 7% by Entergy Power
IRS	Internal Revenue Service
ISO	Independent System Operator
kW	Kilowatt
kWh	Kilowatt-hour(s)
LPSC	Louisiana Public Service Commission
MMBtu	One million British Thermal Units

1

DEFINITIONS (Continued)

MPSC	Mississippi Public Service Commission
MW	Megawatt(s), which equals one thousand kilowatt(s)
MWh	Megawatt-hour(s)
Net debt ratio	Gross debt less cash and cash equivalents divided by total capitalization less cash and cash equivalents
Net MW in operation	Installed capacity owned or operated
Non-Utility Nuclear	Entergy's business segment that owns and operates six nuclear power plants and sells electric power produced by those plants to wholesale customers
NRC	Nuclear Regulatory Commission
NYPA	New York Power Authority
PPA	Purchased power agreement
production cost	Cost in $/MMBtu associated with delivering gas, excluding the cost of the gas
PUCT	Public Utility Commission of Texas
PUHCA 1935	Public Utility Holding Company Act of 1935, as amended
PUHCA 2005	Public Utility Holding Company Act of 2005, which repealed PUHCA 1935, among other things
Registrant Subsidiaries	Entergy Arkansas, Inc., Entergy Gulf States Louisiana, L.L.C., Entergy Louisiana, LLC, Entergy Mississippi, Inc., Entergy New Orleans, Inc., Entergy Texas, Inc., and System Energy Resources, Inc.
River Bend	River Bend Steam Electric Generating Station (nuclear), owned by Entergy Gulf States Louisiana
SEC	Securities and Exchange Commission
SFAS	Statement of Financial Accounting Standards as promulgated by the FASB
System Agreement	Agreement, effective January 1, 1983, as modified, among the Utility operating companies relating to the sharing of generating capacity and other power resources
System Energy	System Energy Resources, Inc.
TIEC	Texas Industrial Energy Consumers
TWh	Terawatt-hour(s), which equals one billion kilowatt-hours
unit-contingent	Transaction under which power is supplied from a specific generation asset; if the asset is unavailable, the seller is not liable to the buyer for any damages
Unit Power Sales Agreement	Agreement, dated as of June 10, 1982, as amended and approved by FERC, among Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy, relating to the sale of capacity and energy from System Energy's share of Grand Gulf
Utility	Entergy's business segment that generates, transmits, distributes, and sells electric power, with a small amount of natural gas distribution
Utility operating companies	Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas
Waterford 3	Unit No. 3 (nuclear) of the Waterford Steam Electric Generating Station, 100% owned or leased by Entergy Louisiana
weather-adjusted usage	Electric usage excluding the effects of deviations from normal weather

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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.

• 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.

Plan to Pursue Separation of Non-Utility Nuclear

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. Enexus Energy Corporation, a wholly-owned subsidiary of Entergy and formerly referred to as SpinCo, will 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 L.L.C., with 50% ownership by Enexus and 50% ownership by Entergy. The EquaGen board of members will be comprised of equal membership from both Entergy and Enexus.

Upon completion of the spin-off, Entergy Corporation's shareholders will own 100% of the common stock in both Enexus and Entergy. Entergy expects that Enexus' business will 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 will primarily be comprised of the Utility business. EquaGen is expected to operate the nuclear assets owned by Enexus, and provide certain services to the Utility's nuclear operations. EquaGen is also expected to offer nuclear services to third parties, including decommissioning, plant relicensing, plant operations, and ancillary services.

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, will remain the operator of the plants after the separation.  Entergy Operations, Inc., the current NRC-licensed operator of Entergy's five Utility nuclear plants, will remain a wholly-owned subsidiary of Entergy and will 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 publish ed 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, and the NRC or a presiding officer designated by the NRC will determine whether a hearing will be granted. If a hearing is granted, the NRC is expected to issue a procedural schedule providing for limited discovery, written testimony and a legislative-type hearing. Under the NRC's procedural rules for license transfer approvals, the NRC Staff will co ntinue to review the application,
 

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prepare a Safety Evaluation Report and issue an approval or denial without regard to whether a hearing request is pending or has been granted. Thus, resolution of the hearing requests is not a prerequisite to obtaining the required NRC approval. On July 28, 2008 the NRC approved Entergy Nuclear Operations, Inc.'s application.

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 and Entergy Nuclear Operations, Inc. requested approval from the Vermont Public Service Board 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. Two Vermont utilities that buy power from Vermont Yankee, the regional planning commission for the area served by Vermont Yankee, a municipality in which the Vermont Yankee training center is located, the union that represents certain Vermont Yankee employees, and two unions that represent certain employees at the Pilgrim plant in Massachusetts petitioned to intervene. Although the Pilgrim unions' petition to intervene was denied, the Pilgrim unions filed for reconsideration or, in the alternative, for participation as amicus curiae, and the Vermont Public Service Board has allowed the unions to p articipate as amicus curiae. Discovery is underway in this proceeding, in which parties can ask questions about or request the production of documents related to the transaction.

In addition, the Vermont Department of Public Service, which is the public advocate in proceedings before the Public Service Board, has prefiled its initial and rebuttal testimony in the case in which the Vermont Department of Public Service 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 Energy's 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 Vermont Department of Public Service's 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 th at 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 Vermont Public Service Board conducted hearings on July 28-30, 2008, during which it considered the testimony prefiled by Entergy Nuclear Vermont Yankee, Entergy Nuclear Operations, Inc., the Vermont Department of Public Service, and the two distribution utilities. Briefing will now follow the hearings, and the Vermont Public Service Board will then issue a decision.

On January 28, 2008, Entergy Nuclear FitzPatrick, Entergy Nuclear Indian Point 2, Entergy Nuclear Indian Point 3, Entergy Nuclear Operations, Inc., and corporate affiliate NewCo (now named 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 Riverkeeper, Inc. have filed objections to the business separation and to the transfer of the FitzPatrick and Indian Point Energy Cente r nuclear power plants, arguing that the debt associated with the spin-off could threaten access to adequate financial resources for those nuclear power plants, that Entergy could potentially be able to terminate revenue sharing agreements with the New York Power Authority (NYPA), the entity from which Entergy purchased the FitzPatrick and Indian Point 3 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.

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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' ruling acknowledged that the proposed process will not facilitate a decision by the NYPSC in September 2008. 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 NYPA revenues from value sharing payments under the value sharing agreement b etween 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. For further discussion of the value sharing agreements, see Note 1 to the financial statements herein. Entergy continues to seek regulatory approval from the NYPSC in a timely manner.

In connection with the separation, Enexus is currently expected to incur up to $4.5 billion of debt in the form of debt securities. The debt will be incurred in the following transactions:

Enexus is expected to issue up to $3.5 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 $3.5 billion of debt securities that Entergy plans to issue prior to the separation. As a result of the exchange (should the exchange occur), the holders of the debt securities that Entergy plans to issue prior to the separation will become holders of the up to $3.5 billion of Enexus debt securities.

Enexus is expected to incur the balance of the debt through one or more public or private offerings of notes or other debt securities.

Out of the proceeds Enexus receives from the public or private offerings, 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 intercompany debt. Enexus will not receive any proceeds from either the issuance of up to $3.5 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 or repurchase Entergy shares. The amount to be paid to Entergy, the amount and term of the debt Enexus will incur, and the type of debt and entity that will incur the debt have not been finally determined, but will 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. Additionally, Entergy expects Enexus to enter into one or more credit facilities or other financing arrangements intended to support Enexus' working capital needs, collateral obligations, and other corporate needs arising from hedging and normal course of business requirements.

5

Entergy is targeting the fourth quarter 2008 as the effective date for the spin-off and EquaGen transactions to be completed. Entergy expects the transactions to qualify for tax-free treatment for U.S. federal income tax purposes for both Entergy and its shareholders, and Entergy submitted a private letter ruling request to the IRS in April 2008 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.

Results of Operations

Income Statement Variances

Second Quarter 2008 Compared to Second Quarter 2007

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

	Utility	Non-Utility Nuclear	Parent & Other (1)	Entergy
	(In Thousands)
2nd Quarter 2007 Consolidated Net Income	$148,194	$108,726	$10,682	$267,602
Net revenue (operating revenue less fuel   expense, purchased power, and other   regulatory charges/credits)	52,329	134,664	8,595	195,588
Other operation and maintenance expenses	17,895	25,546	27,198	70,639
Taxes other than income taxes	5,980	4,156	(542)	9,594
Depreciation and amortization	2,547	6,612	165	9,324
Other income	4,895	(24,551)	(1,941)	(21,597)
Interest charges	(929)	9,227	(19,739)	(11,441)
Other expenses	6,250	9,709	3	15,962
Income taxes	13,961	19,973	42,627	76,561
2nd Quarter 2008 Consolidated Net Income	$159,714	$143,616	($32,376)	$270,954

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

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

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Net Revenue

Utility

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

	Amount
	(In Millions)
2007 net revenue	$1,129.5
Volume/weather	42.3
Other	10.0
2008 net revenue	$1,181.8

The volume/weather variance is primarily due to increased electricity usage, including the effect of more favorable weather compared to the same period in 2007 and higher sales during the unbilled period. Billed retail electricity usage increased a total of 594 GWh in the residential and commercial sectors, an increase of 4.4%.

Non-Utility Nuclear

Net revenue increased for Non-Utility Nuclear from $419 million for the second quarter 2007 to $553 million for the second quarter 2008 primarily due to higher pricing in its contracts to sell power and increased production resulting from fewer outage days and the acquisition of the Palisades plant on April 11, 2007. In addition to refueling outages, second quarter 2007 was affected by a 28 day unplanned outage. Following are key performance measures for Non-Utility Nuclear for the second quarter 2008 and 2007:

	2008	2007
Net MW in operation at June 30	4,998	4,998
Average realized price per MWh	$58.22	$51.28
GWh billed	10,145	8,896
Capacity factor	92%	82%
Refueling Outage Days:
Indian Point 2	19	-
Pilgrim	-	33
Vermont Yankee	-	24

Other Operation and Maintenance Expenses

Utility

Other operation and maintenance expenses increased from $461 million for the second quarter 2007 to $479 million for the second quarter 2008 primarily due to:

an increase of $8 million in loss reserves, including storm damage reserves at Entergy Mississippi;

an increase of $6 million in storm damage charges as a result of several storms hitting Entergy Arkansas' service territory in 2008. Entergy Arkansas discontinued regulatory storm reserve accounting beginning July 2007 as a result of the APSC order issued in Entergy Arkansas' rate case. As a result, non-capital storm expenses are charged to other operation and maintenance expenses;

an increase of $6 million in payroll-related costs; and

various other insignificant factors.

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These increases were partially offset by a reimbursement of $7 million of costs in connection with a litigation settlement.

Non-Utility Nuclear

Other operation and maintenance expenses increased from $175 million for the second quarter 2007 to $201 million for the second quarter 2008 primarily due to deferring costs from one refueling outage in 2008 compared to two refueling outages in second quarter 2007, in addition to the acquisition of the Palisades plant in April 2007. Other operation and maintenance expenses associated with the Palisades plant were $31 million for the second quarter 2008 compared to $24 million for the second quarter 2007.

Parent & Other

Other operation and maintenance expenses increased for the parent company, Entergy Corporation, for the second quarter 2008 primarily due to outside services costs related to the planned spin-off of the Non-Utility Nuclear business.

Other Income

Other income decreased primarily due to a $24.4 million charge to interest income in the second quarter 2008 resulting from the recognition of the other than temporary impairment of certain securities held in Non-Utility Nuclear's decommissioning trust funds.

Income Taxes

The effective income tax rates for the second quarters of 2008 and 2007 were 39.9% and 28.0%, respectively. The difference in the effective income tax rate versus the statutory rate of 35% for the second quarter 2008 is primarily due to state income taxes and book and tax differences for utility plant items. The reduction in the effective income tax rate versus the statutory rate of 35% for the second quarter 2007 is primarily due to the resolution of tax audit issues in the 2002-2003 audit cycle, 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.

Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Following are income statement variances for Utility, Non-Utility Nuclear, Parent & Other, and Entergy comparing the six months ended June 30, 2008 to the six months ended June 30, 2007 showing how much the line item increased or (decreased) in comparison to the prior period:

	Utility	Non-Utility Nuclear	Parent & Other (1)	Entergy
	(In Thousands)
2007 Consolidated Net Income	$252,644	$236,896	($9,743)	$479,797
Net revenue (operating revenue less fuel     expense, purchased power, and other     regulatory charges/credits)	79,620	338,153	7,258	425,031
Other operation and maintenance expenses	29,871	60,183	27,477	117,531
Taxes other than income taxes	(8,518)	9,243	(5,243)	(4,518)
Depreciation and amortization	1,572	20,071	256	21,899
Other income	(13,572)	(21,687)	(5,929)	(41,188)
Interest charges	(6,403)	13,732	(14,213)	(6,884)
Other expenses	7,797	24,608	6	32,411
Income taxes	17,512	60,211	45,775	123,498
2008 Consolidated Net Income	$276,861	$365,314	($62,472)	$579,703

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

Net Revenue

Utility

Following is an analysis of the change in net revenue comparing the six months ended June 30, 2008 to the six months ended June 30, 2007.

	Amount
	(In Millions)
2007 net revenue	$2,136.8
Volume/weather	43.4
Fuel recovery	18.3
Rider revenue	15.3
Base revenues	15.1
Purchased power capacity	(19.1)
Other	6.6
2008 net revenue	$2,216.4

The volume/weather variance is primarily due to increased electricity usage, including the effect of more favorable weather compared to the same period in 2007. Billed retail electricity usage increased a total of 936 GWh in the residential and commercial sectors, an increase of 3.4%.

The fuel recovery variance resulted primarily from a reserve for potential rate refunds in the first quarter 2007 in Texas as a result of a PUCT ruling related to the application of past PUCT rulings addressing transition to competition in Texas.

The rider revenue variance is primarily due to:

an increase in the Attala power plant costs that are 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 base revenues variance is primarily due to the interim surcharge to collect $10 million in under-recovered incremental purchased capacity costs incurred through July 2007 in Texas. The surcharge was collected over a two-month period beginning February 2008. The incremental capacity recovery rider and PUCT approval is discussed in Note 2 to the financial statements in the Form 10-K. The variance is also due to a formula rate plan increase effective July 2007 at Entergy Mississippi.

The purchased power capacity variance is due to the amortization of deferred capacity costs and is partially offset in base revenues due to the incremental purchased capacity costs recovered through the interim surcharge, as discussed above.

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Non-Utility Nuclear

Net revenue increased for Non-Utility Nuclear from $840 million for the six months ended June 30, 2007 to $1,178 million for the six months ended June 30, 2008 primarily due to higher pricing in its contracts to sell power, additional production resulting from the acquisition of the Palisades plant in April 2007, and fewer outage days. In addition to refueling outages, second quarter 2007 was affected by a 28 day unplanned outage. Palisades contributed $154 million of net revenue for the six months ended June 30, 2008 compared to $70 million of net revenue for the six months ended June 30, 2007. Included in the Palisades net revenue is $38 million and $15 million for the six months ended June 30, 2008 and 2007, respectively, of amortization of the Palisades purchased power agreement liability, which is non-cash revenue and is discussed in Note 15 to the financial statements in the Form 10-K. Following are key performance measures for Non-Utility Nuclear for the six months ended Ju ne 30, 2008 and 2007:

	2008	2007
Net MW in operation at June 30	4,998	4,998
Average realized price per MWh	$59.89	$53.13
GWh billed	20,905	17,211
Capacity factor	95%	86%
Refueling Outage Days:
Indian Point 2	26	-
Indian Point 3	-	24
Pilgrim	-	33
Vermont Yankee	-	24

Other Operation and Maintenance Expenses

Utility

Other operation and maintenance expenses increased from $870 million for the six months ended June 30, 2007 to $899 million for the six months ended June 30, 2008 primarily due to:

an increase of $16 million in fossil expenses primarily due to higher costs for plant maintenance outages as a result of differing outage schedules for 2008 compared to 2007;

an increase of $16 million in storm damage charges as a result of several storms hitting Entergy Arkansas' service territory in 2008. Entergy Arkansas discontinued regulatory storm reserve accounting beginning July 2007 as a result of the APSC order issued in Entergy Arkansas' rate case. As a result, non-capital storm expenses are charged to other operation and maintenance expenses; and

an increase of $9 million in loss reserves, including storm damage reserves at Entergy Mississippi.

The increase was partially offset by a reimbursement of $7 million of costs in connection with a litigation settlement.

Non-Utility Nuclear

Other operation and maintenance expenses increased from $322 million for the six months ended June 30, 2007 to $382 million for the six months ended June 30, 2008 primarily due to deferring costs from one refueling outage in 2008 compared to three refueling outages in 2007, in addition to the acquisition of the Palisades plant in April 2007. Other operation and maintenance expenses associated with the Palisades plant were $60 million for the six months ended June 30, 2008 compared to $24 million for the six months ended June 30, 2007.

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Parent & Other

Other operation and maintenance expenses increased for the parent company, Entergy Corporation, for the six months ended June 30, 2008 primarily due to outside services costs related to the planned spin-off of the Non-Utility Nuclear business, including approximately $23.7 million of such costs in the second quarter 2008.

Other Income

Other income decreased primarily due to approximately $27 million in charges to interest income in 2008 resulting from the recognition of the other than temporary impairment of certain securities held in Non-Utility Nuclear's decommissioning trust funds. Other factors contributing to the decrease were a reduction in the allowance for equity funds used during construction in the Utility due to a revision in the first quarter 2007 related to removal costs and a reduction in carrying charges on storm costs as recovery of some of those costs has been completed.

Income Taxes

The effective income tax rates for the six months ended June 30, 2008 and 2007 were 38.9% and 33.9%, respectively. The difference in the effective income tax rate versus the statutory rate of 35% for the six months ended June 30, 2008 is primarily due to state income taxes and book and tax differences for utility plant items, partially offset by 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. The reduction in the effective income tax rate versus the statutory rate of 35% for the six months ended June 30, 2007 is primarily due to the resolution of tax audit issues in the 2002-2003 audit cycle, 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.

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.

Capital Structure

Entergy's capitalization is balanced between equity and debt, as shown in the following table. The increase in the debt to capital percentage from 2007 to 2008 is primarily the result of additional borrowings under Entergy Corporation's revolving credit facilities, along with a decrease in shareholders' equity primarily due to an increase in accumulated other comprehensive loss and repurchases of common stock, offset by an increase in retained earnings. The increase in accumulated other comprehensive loss is primarily due to derivative instrument fair value changes. See Note 1 (Derivative Financial Instruments and Commodity Derivatives)and Note 16 to the financial statements in the Form 10-K for additional discussion of the accounting treatment of derivative instruments. The increase in the debt to capital percentage is in line with Entergy's financial and risk management aspirations.

	June 30, 2008	December 31, 2007
Net debt to net capital	58.3%	54.7%
Effect of subtracting cash from debt	2.4%	2.9%
Debt to capital	60.7%	57.6%

Net debt consists of debt less cash and cash equivalents. Debt consists of notes payable, capital lease obligations, and long-term debt, including the currently maturing portion. Capital consists of debt, 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.

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As discussed in the Form 10-K, Entergy Corporation has in place a $3.5 billion credit facility that expires in August 2012. Entergy Corporation has the ability to issue letters of credit against the total borrowing capacity of the facility. As of June 30, 2008, amounts outstanding under the credit facility are:

Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$2,772	$72	$656

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

Capital Expenditure Plans and Other Uses of Capital

See the table and discussion in the Form 10-K under "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources - Capital Expenditure Plans and Other Uses of Capital," that sets forth the amounts of planned construction and other capital investments by operating segment for 2008 through 2010. Following is an update to the discussion in the Form 10-K.

Little Gypsy Repowering Project

The preconstruction and operating air permits for the Little Gypsy repowering project were issued by the Louisiana Department of Environmental Quality (LDEQ) in November 2007 under then-effective federal and state air regulations, including the EPA's Clean Air Mercury Rule that had been issued in 2005 (CAMR 2005). As discussed in more detail in part I, Item 1, "Environmental Regulation, Clean Air Act and Subsequent Amendments, Hazardous Air Pollutants" in the Form 10-K, in February 2008 the U.S. Court of Appeals for the D.C. Circuit struck down CAMR 2005. The D.C. Circuit decision requires utilities that have not yet begun construction of the facility in question to undergo a case-by-case Maximum Achievable Control Technology (MACT) analysis for construction or reconstruction of emission units pursuant to the Clean Air Act before beginning construction. The Little Gypsy project as currently configured is expected to meet MACT standards. Little Gypsy received its construction permit bef ore a formal MACT analysis was required, however, and Entergy Louisiana has sought a MACT determination from the LDEQ. The filing was made in June 2008, and the LDEQ has certified that the filing is complete. A decision on the MACT determination is expected by first quarter 2009. Entergy Louisiana also is awaiting permit determinations from several additional agencies. These permits are unrelated to CAMR 2005 and always have been part of the construction process. Onsite construction of the project was scheduled to begin in July 2008, but obtaining the MACT determination will cause a delay in the start of construction, which Entergy Louisiana now expects to begin in mid-year 2009. This delays the expected commercial operation date of the project to mid-2013. The LPSC approved the temporary suspension of Phase II of the Little Gypsy proceedings because Entergy Louisiana must update its estimated project cost and schedule in order to support the request to recover cash earnings on its construction work i n progress costs. Entergy Louisiana plans to refile the Phase II case in September 2008, and a decision is expected in the first quarter 2009. The LPSC Phase I order has been appealed to the state district court in Baton Rouge, Louisiana by a group led by the Sierra Club and represented by the Tulane Environmental Law Clinic. A procedural schedule for the appeal has not been set.

The delayed construction of the Little Gypsy repowering project is expected to increase the total project cost from approximately $1.55 billion to $1.76 billion, primarily due to price escalation on non-contracted equipment and material and increased carrying cost due to the extended construction period.

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Waterford 3 Steam Generator Replacement Project

As discussed in more detail in the Form 10-K, Entergy Louisiana plans to replace the Waterford 3 steam generators, along with the reactor vessel closure head and control element drive mechanisms, in 2011.  In June 2008, Entergy Louisiana filed with the LPSC for approval of the project, including full cost recovery. Entergy Louisiana estimates in the filing that it will spend approximately $511 million on this project. The filing seeks relief in two phases. Phase I seeks certification within 120 days that the public convenience and necessity would be served by undertaking this project. Among other relief requested, Entergy Louisiana is also seeking approval for a procedure to synchronize permanent base rate recovery when the project is placed in service, either by a formula rate plan or base rate filing. In Phase II, Entergy Louisiana will seek cash earnings on construction work in progress. A status conference was held on July 31, 2008, and a procedural schedule for Phase I was adopted providing for hearings in October 2008 and LPSC consideration in December 2008.

White Bluff Environmental Project

The planned construction and other capital investments disclosure in the Form 10-K includes approximately $24 million for initial spending during the 2008-2010 period on installation of scrubbers and low NOx burners at Entergy Arkansas' White Bluff coal plant, which under current environmental regulations must be operational by September 2013. The project remains in the planning stages and has not been fully designed, but the latest conceptual cost estimate has gone up significantly from previous estimates due to increases in equipment, commodity, and labor costs. These estimates indicate that Entergy Arkansas' share of the project could cost approximately $630 million compared to the $375 million reported in the Form 10-K. Entergy continues to review potential environmental spending needs and financing alternatives for any such spending, and future spending estimates could change based on the results of this continuing analysis.

Sources of Capital

The short-term borrowings of the Registrant Subsidiaries and certain other Entergy subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through March 31, 2010, as established by a FERC order issued March 31, 2008 (except for Entergy Gulf States Louisiana and Entergy Texas, which are effective through November 8, 2009, as established by an earlier FERC order). See Note 4 to the financial statements for further discussion of Entergy's short-term borrowing limits.

Hurricane Katrina and Hurricane Rita

In August and September 2005, Hurricanes Katrina and Rita caused catastrophic damage to large 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. The storms and flooding resulted in widespread power outages, significant damage to electric distribution, transmission, and generation and gas infrastructure, and the loss of sales and customers due to mandatory evacuations and the destruction of homes and businesses. Entergy has pursued a broad range of initiatives to recover storm restoration and business continuity costs, including obtaining reimbursement of certain costs covered by insurance and pursuing recovery through existing or new rate mechanisms regulated by the FERC and local regulatory bodies, including the issuance of securitization or bonds. Following are updates regarding Entergy's cost recovery efforts.

Storm Cost Financings

In March 2008, Entergy Gulf States Louisiana, Entergy Louisiana, and the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, filed at the LPSC an application requesting that the LPSC grant financing orders authorizing the financing of Entergy Gulf States Louisiana and Entergy Louisiana storm costs, storm reserves, and issuance costs pursuant to Act 55 of the Louisiana Legislature (Act 55 financings). The Act 55 financings are expected to produce additional customer benefits as compared to Act 64 traditional securitization.  Entergy Gulf States Louisiana and Entergy Louisiana also filed an application requesting LPSC approval for ancillary issues including the mechanism to flow
 

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charges and savings to customers via a Storm Cost Offset rider.  On April 3, 2008, the Louisiana State Bond Commission granted preliminary approval for the Act 55 financings.  On April 8, 2008, the Louisiana Public Facilities Authority (LPFA), which is the issuer of the bonds pursuant to the Act 55 financings, approved requests for the Act 55 financings.  On April 10, 2008, Entergy Gulf States Louisiana and Entergy Louisiana and the LPSC Staff filed with the LPSC an uncontested stipulated settlement that includes Entergy Gulf States Louisiana and Entergy Louisiana's proposals under the Act 55 financings, which includes a commitment to pass on to customers a minimum of $10 million and $30 million of customer benefits, respectively.  On April 16, 2008, the LPSC approved the settlement and issued two financing orders and one ratemaking order intended to facilitate implementation of the Act 55 financings.  On May 6, 2008, the State Bond Commission voted to approve the Act 55 financings.

On July 29, 2008, the LPFA issued $679 million in bonds under the aforementioned Act 55.  From the bond proceeds received by Entergy Louisiana from the LURC, Entergy Louisiana invested $527 million in affiliate securities.  The LURC deposited $152 million in a restricted escrow account as a storm damage reserve for Entergy Louisiana.  As approved by the April 16, 2008 LPSC orders, Entergy Louisiana withdrew $17.8 million from the restricted escrow account and also invested this amount in affiliate securities.

Entergy Gulf States Louisiana expects that in September 2008 the LPFA will issue $273 million in bonds under the aforementioned Act 55.  From the bond proceeds expected to be received by Entergy Gulf States Louisiana from the LURC, Entergy Gulf States Louisiana is expected to invest $186 million in affiliate securities.  In addition, Entergy Gulf States Louisiana expects the LURC to deposit $87 million to a restricted escrow account as a storm damage reserve for Entergy Gulf States Louisiana.  As approved by the April 16, 2008 LPSC orders, it is expected that Entergy Gulf States Louisiana will withdraw $1.7 million from the restricted escrow account and will also invest this amount in affiliate securities.

Insurance Claims

See Note 8 to the financial statements in the Form 10-K for a discussion of Entergy's conventional property insurance program and its Hurricane Katrina and Hurricane Rita claims.

In April 2008, Entergy received from its primary insurer $53.6 million of additional insurance proceeds on its Hurricane Katrina claim, and almost all of the April 2008 proceeds were allocated to Entergy New Orleans.

Entergy has settled its lawsuit against one of its excess insurers on the Hurricane Katrina claim, and in July 2008 received $71.5 million in proceeds on the claim. The July 2008 proceeds were allocated as follows: $2.0 million to Entergy Arkansas, $3.7 million to Entergy Gulf States Louisiana, $12.4 million to Entergy Louisiana, $1.8 million to Entergy Mississippi, and $48.4 million to Entergy New Orleans, with the remainder allocated in smaller amounts to other Entergy subsidiaries.

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Cash Flow Activity

As shown in Entergy's Consolidated Statements of Cash Flows, cash flows for the six months ended June 30, 2008 and 2007 were as follows:

		2008	2007
		(In Millions)
Cash and cash equivalents at beginning of period		$1,253	$1,016
Effect of reconsolidating Entergy New Orleans		-	17
Cash flow provided by (used in):
	Operating activities	914	964
	Investing activities	(1,008)	(1,016)
	Financing activities	(73)	339
Net increase (decrease) in cash and cash equivalents		(167)	287
Cash and cash equivalents at end of period		$1,086	$1,320

Operating Activities

Entergy's cash flow provided by operating activities decreased by $50 million for the six months ended June 30, 2008 compared to the six months ended June 30, 2007. Following are cash flows from operating activities by segment:

Utility provided $398 million in cash from operating activities in 2008 compared to providing $764 million in 2007 primarily due to decreased collection of fuel costs in 2008 and the receipt of $177 million of Community Development Block Grant funds by Entergy New Orleans in 2007. Fuel prices have been increasing, and due to the time lag before the fuel recovery rates increase in response, the Utility has under-recovered fuel costs thus far in 2008.

Non-Utility Nuclear provided $594 million in cash from operating activities in 2008 compared to providing $259 million in 2007, primarily due to an increase in net revenue, partially offset by an increase in operation and maintenance costs.

Parent & Other used approximately $78 million in cash in operating activities in 2008 and used approximately $59 million in cash in operating activities in 2007.

Investing Activities

Net cash used in investing activities decreased by $8 million for the six months ended June 30, 2008 compared to the six months ended June 30, 2007. The following significant investing cash flow activity occurred in the six months ended June 30, 2008 and 2007:

Construction expenditures were $62 million higher in 2008 than in 2007, primarily due to increased spending on various projects by the Utility that are discussed further in "Capital Expenditure Plans" in the Form 10-K.

In April 2007, Non-Utility Nuclear purchased the 798 MW Palisades nuclear power plant located near South Haven, Michigan for a net cash payment of $336 million.

In March 2008, Entergy Gulf States Louisiana purchased the Calcasieu Generating Facility, a 322 MW simple-cycle, gas-fired power plant located near the city of Sulphur in southwestern Louisiana, for approximately $56.4 million.

Non-Utility Nuclear made a $72 million payment to NYPA in 2008 under the value sharing agreement associated with the acquisition of the Fitzpatrick and Indian Point 3 power plants. See Note 1 to the financial statements herein for additional discussion of the value sharing agreement.

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In 2008, Non-Utility Nuclear posted $102 million of cash as collateral in support of its agreements to sell power.

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.

Financing Activities

Financing activities used $73 million for the six months ended June 30, 2008 and provided $339 million for the six months ended June 30, 2007. The following significant financing cash flow activity occurred in the six months ended June 30, 2008 and 2007:

Entergy Corporation increased the net borrowings under its revolving credit facility by $521 million in the six months ended June 30, 2008 and by $1,150 million in the six months ended June 30, 2007. See Note 4 to the financial statements for a description of the Entergy Corporation credit facilities.

The Utility operating companies increased the borrowings outstanding on their long-term credit facilities by $230 million in the six months ended June 30, 2008.

A subsidiary of Entergy Texas issued $329.5 million of securitization bonds in June 2007. See Note 5 to the financial statements in the Form 10-K for additional information regarding the securitization bonds.

Entergy Corporation repaid $87 million of notes payable at their maturity in March 2008.

Entergy Mississippi redeemed $100 million of first mortgage bonds in 2007.

The Utility operating companies increased the borrowings outstanding on their short-term credit facilities by $150 million in the six months ended June 30, 2008.

Entergy Corporation repurchased $370 million of its common stock in the six months ended June 30, 2008 and $825 million of its common stock in the six months ended June 30, 2007.

Entergy Corporation increased the dividend on its common stock. The quarterly dividend was $0.54 per share in 2007 and $0.75 per share for the first two quarters in 2008.

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, and market and credit risk sensitive instruments. Following are updates to the information provided in the Form 10-K.

State and Local Rate Regulation

See the Form 10-K for a chart summarizing material rate proceedings. See Note 2 to the financial statements herein for updates to the proceedings discussed in that chart.

Federal Regulation

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

System Agreement Proceedings

Production Cost Equalization Proceeding Commenced by the LPSC

See the Form 10-K for a discussion of the June 2005 FERC decision in the System Agreement litigation that had been commenced by the LPSC, which was essentially affirmed in the FERC's decision in a December 2005 order on rehearing. The LPSC, APSC, MPSC, and the AEEC appealed the FERC's decision to the United States Court of Appeals for the D.C. Circuit. Entergy and the City of New Orleans intervened in the various appeals. The D.C. Circuit issued its decision in April 2008. The D.C. Circuit affirmed the FERC's decision in most respects, but remanded the case to the FERC for further proceedings and reconsideration of its conclusion that it was prohibited from ordering refunds and its determination to

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implement the bandwidth remedy commencing with calendar year 2006 production costs (with the first payments/receipts commencing in June 2007), rather than commencing the remedy on June 1, 2005. The D.C. Circuit concluded the FERC had failed so far in the proceeding to offer a reasoned explanation regarding these issues. On July 17, 2008, the Utility operating companies filed with FERC a motion proposing additional procedures on the remanded issues.

Rough Production Cost Equalization Rates

2007 Rate Filing Based on Calendar Year 2006 Production Costs

See the Form 10-K for a discussion of the proceeding in which Entergy filed the rates to implement the FERC's orders in the production cost equalization proceeding. Intervenor cross-answering testimony was filed during March and April 2008, in which the intervenors and FERC Staff advocate a number of positions on issues that affect the level of production costs the individual Utility operating companies are permitted to reflect in the bandwidth calculation, including the level of depreciation and decommissioning expense for nuclear facilities. The effect of the various positions would be to reallocate costs among the Utility operating companies. Additionally, the APSC, while not taking a position on whether Entergy Arkansas was imprudent for not exercising its right of first refusal to repurchase a portion of the Independence plant in 1996 and 1997 as alleged by the LPSC, alleges that if the FERC finds Entergy Arkansas to be imprud ent for not exercising this option, the FERC should disallow recovery from customers by Entergy of approximately $43 million of increased costs. On April 28, 2008 the Utility operating companies filed rebuttal testimony refuting the allegations of imprudence concerning the decision not to acquire the portion of the Independence plant, explaining why the bandwidth payments are properly recoverable under the AmerenUE contract, and explaining why the positions of FERC Staff and intervenors on the other issues should be rejected. A hearing in this proceeding concluded in July 2008, post-hearing briefing is scheduled to conclude in August 2008, and the ALJ is expected to issue an initial decision in September 2008.

As discussed in the Form 10-K, the Utility operating companies had also filed with the FERC during 2007 certain proposed modifications to the rough production cost equalization calculation. The FERC rejected certain of the proposed modifications, accepted certain of the proposed modifications without further proceedings, and set two of the proposed modifications for hearing and settlement procedures. With respect to the proceeding involving changes to the functionalization of costs to the production function, a hearing was held in March 2008 and the ALJ issued an Initial Decision in June 2008 finding the modifications proposed by the Utility operating companies to be just and reasonable. Following briefing, the matter will be submitted to the FERC for decision. In the second proceeding, a contested settlement supported by the Utility operating companies has been submitted to the Settlement ALJ. In conjunction with the second proceeding, the LPSC has appealed to the Court of Appeal s for the D.C. Circuit the FERC's determination that changes proposed by the Utility operating companies and accepted by the FERC can become effective for the next bandwidth calculation even though such bandwidth calculation may include production costs incurred prior to the date the change is proposed by the Utility operating companies.

The intervenor AmerenUE has argued that its current wholesale power contract with Entergy Arkansas, pursuant to which Entergy Arkansas sells power to AmerenUE, does not permit Entergy Arkansas to flow through to AmerenUE any portion of Entergy Arkansas' bandwidth payment.  According to AmerenUE, Entergy Arkansas has sought to collect from AmerenUE approximately $14.5 million of the 2007 Entergy Arkansas bandwidth payment.  The AmerenUE contract is scheduled to expire in August 2009. In April 2008, AmerenUE filed a complaint with the FERC seeking refunds of this amount, plus interest, in the event the FERC ultimately determines that bandwidth payments are not properly recovered under the AmerenUE contract.

On March 31, 2008, the LPSC filed a complaint with the FERC seeking, among other things, three amendments to the rough production cost equalization bandwidth formula. On April 22, 2008, the Utility operating companies filed an answer to the LPSC complaint urging the FERC to reject two of the proposed amendments and not opposing the third. On July 2, 2008, the FERC issued an order that, among other things, ordered the Utility operating companies to implement the LPSC's proposed amendment that they did not oppose and setting two of the LPSC's proposed amendments for hearing and settlement proceedings.

17

2008 Rate Filing Based on Calendar Year 2007 Production Costs

In May 2008, Entergy filed with the FERC the rates for the second year to implement the FERC's orders in the System Agreement proceeding that are discussed in the Form 10-K.The filing shows the following payments/receipts among the Utility operating companies for 2008, based on calendar year 2007 production costs, commencing for service in June 2008, are necessary to achieve rough production cost equalization under the FERC's orders:

	Payments or (Receipts)
	(In Millions)
Entergy Arkansas	$252
Entergy Gulf States Louisiana	($124)
Entergy Louisiana	($35)
Entergy Mississippi	($20)
Entergy New Orleans	($7)
Entergy Texas	($66)

Several parties intervened in the proceeding at the FERC, including the APSC, the LPSC, and AmerenUE, which have also filed protests. Several other parties, including the MPSC and the City Council, have intervened in the proceeding without filing a protest. On July 29, 2008, the FERC set the proceeding for hearing and settlement procedures. A settlement judge should be appointed and a conference scheduled in August 2008.

Entergy Arkansas will pay $36 million per month for seven months in 2008, and began making the payments in June 2008. As discussed in Note 2 to the financial statements, the APSC has approved a production cost allocation rider for recovery from customers of the retail portion of the costs allocated to Entergy Arkansas.

Independent Coordinator of Transmission

In the FERC's April 2006 order that approved 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. The Utility operating companies also filed with the FERC in April 2007 a request to make certain corrections and limited modifications to the current WPP tariff provisions. The Utility operating companies have filed status reports with the FERC notifying the FERC that, due to unexpected issues with the development of the WPP software and testing, the WPP is still not operational. The Utility operating companies filed a revised tariff with the FERC on January 31, 2008 to address issues identified during the testing of the WPP. The Utility operating co mpanies requested the FERC to rule on the proposed amendments by April 30, 2008 and allow them to go into effect May 11, 2008, following which the WPP would be expected to become operational. In May 2008, the FERC determined it would be premature to implement the WPP on May 11, 2008 as the WPP has not been shown to be just and reasonable. Accordingly, the FERC conditionally accepted and suspended Entergy's proposed tariff amendments for five months from the requested effective date, to become effective October 11, 2008, or on an earlier date, subject to refund and subject to a further order on proposed tariff revisions directed to be filed in the order. The FERC stated that it will consider allowing an effective date earlier than October 11, 2008, if the ICT agrees that the model is ready and Entergy files the required tariff revisions no later than 60 days before that date. The FERC also denied the requests for a technical conference at this time and indicated it will reassess the need for such a techni cal conference after the WPP is functioning.

18

Market and Credit Risk Sensitive Instruments

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, 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 as of June 30, 2008 under physical or financial contracts (2008 represents the remaining two quarters of the year):

		2008	2009	2010	2011	2012
Non-Utility Nuclear:
Percent of planned energy output sold forward:
	Unit-contingent	48%	48%	31%	29%	17%
	Unit-contingent with availability guarantees (1)	40%	35%	28%	14%	7%
	Firm liquidated damages	5%	0%	0%	0%	0%
	Total	93%	83%	59%	43%	24%
Planned energy output (TWh)		21	41	40	41	41
Average contracted price per MWh (2)		$55	$61	$58	$55	$54

(1)

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

(2)

The Vermont Yankee acquisition included a 10-year PPA under which the former owners will buy most of the power produced by the plant, which is 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, beginning in November 2005, if power market prices drop below PPA prices, which has not happened thus far and is not expected in the foreseeable future.

Entergy's Non-Utility Nuclear business' purchase of the FitzPatrick and Indian Point 3 plants from NYPA included value sharing agreements with NYPA. In October 2007, NYPA and the subsidiaries that own the FitzPatrick and Indian Point 3 plants amended and restated the value sharing agreements to clarify and amend certain provisions of the original terms. Under the amended value sharing agreements, Entergy's Non-Utility Nuclear business agreed to make annual payments to NYPA based on the generation output of the Indian Point 3 and FitzPatrick plants from January 2007 through December 2014. Entergy's Non-Utility Nuclear business will pay NYPA $6.59 per MWh for power sold from Indian Point 3, up to an annual cap of $48 million, and $3.91 per MWh for power sold from FitzPatrick, up to an annual cap of $24 million. The annual payment for each year is due by January 15 of the following year. If Entergy or an Entergy affiliate ceases to own the plants, then, after January 2009, the annual pay ment obligation terminates for generation after the date that Entergy ownership ceases. We believe that the contractual obligation to make value sharing payments to NYPA, other than for 2008 generation output, will terminate if the Non-Utility Nuclear spin-off transaction is completed. On June 3, 2008, NYPA informed Entergy in writing that it disagrees with Entergy's interpretation of the termination provisions of the agreement. In addition, in regulatory proceedings in New York, the Administrative Law Judges 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 Administrative Law Judges believe should be considered by the New York Public Service Commission in making its public interest determination.

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

19

collateral to satisfy these requirements is an Entergy Corporation guaranty. Cash and letters of credit are also acceptable forms of collateral. At June 30, 2008, based on power prices at that time, Entergy had in place as collateral $1,501 million of Entergy Corporation guarantees for wholesale transactions, including $64 million of guarantees that support letters of credit and $102 million of cash collateral. The assurance requirement associated with Non-Utility Nuclear is estimated to increase by an amount of up to $302 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 June 30, 2008 (2008 represents the remaining two quarters of the year):

		2008	2009	2010	2011	2012
Non-Utility Nuclear:
Percent of capacity sold forward:
	Bundled capacity and energy contracts	26%	27%	26%	27%	19%
	Capacity contracts	62%	38%	31%	15%	2%
	Total	88%	65%	57%	42%	21%
Planned net MW in operation		4,998	4,998	4,998	4,998	4,998
Average capacity contract price per kW per month		$2.0	$2.0	$3.4	$3.7	$3.5
Blended Capacity and Energy (based on revenues)
% of planned generation and capacity sold forward		87%	74%	47%	31%	15%
Average contract revenue per MWh		$57	$62	$61	$57	$54

As of June 30, 2008, approximately 96% of Non-Utility Nuclear's counterparty exposure from energy and capacity contracts is with counterparties with public investment grade credit ratings.

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.

New Accounting Pronouncements

In March 2008 the FASB issued Statement of Financial Accounting Standards No. 161 "Disclosures about Derivative Instruments and Hedging Activities, an amendment of FASB Statement No. 133" (SFAS 161), which requires enhanced disclosures about an entity's derivative and hedging activities. SFAS 161 requires qualitative disclosures about objectives and strategies for using derivatives, quantitative disclosures about fair value amounts of and gains and losses on derivative instruments, and disclosures about credit-risk-related contingent features in derivative agreements. SFAS 161 is effective for financial statements issued for fiscal years and interim periods beginning after November 15, 2008.

20

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended		Six Months Ended
	2008	2007	2008	2007
	(In Thousands, Except Share Data)
OPERATING REVENUES
Electric	$2,524,222	$2,194,644	$4,570,449	$4,306,104
Natural gas	53,985	42,909	143,380	127,861
Competitive businesses	686,064	531,799	1,415,176	1,029,446
TOTAL	3,264,271	2,769,352	6,129,005	5,463,411
OPERATING EXPENSES
Operating and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale	726,836	595,602	1,267,337	1,383,014
Purchased power	748,203	601,000	1,368,845	1,045,239
Nuclear refueling outage expenses	55,840	44,614	107,098	87,589
Other operation and maintenance	710,309	639,670	1,321,577	1,204,046
Decommissioning	46,816	42,080	92,812	79,910
Taxes other than income taxes	125,942	116,348	234,513	239,031
Depreciation and amortization	247,977	238,653	492,962	471,063
Other regulatory charges - net	34,239	13,345	69,519	36,885
TOTAL	2,696,162	2,291,312	4,954,663	4,546,777
OPERATING INCOME	568,109	478,040	1,174,342	916,634
OTHER INCOME
Allowance for equity funds used during construction	9,085	7,459	18,371	24,717
Interest and dividend income	23,399	53,948	77,680	111,058
Equity in earnings (loss) of unconsolidated equity affiliates	(2,572)	477	(3,501)	2,101
Miscellaneous - net	3,916	(6,459)	(7,640)	(11,778)
TOTAL	33,828	55,425	84,910	126,098
INTEREST AND OTHER CHARGES
Interest on long-term debt	119,903	124,057	243,047	247,156
Other interest - net	28,030	33,553	60,567	65,768
Allowance for borrowed funds used during construction	(4,937)	(4,386)	(10,053)	(14,915)
Preferred dividend requirements and other	4,975	6,188	9,973	12,409
TOTAL	147,971	159,412	303,534	310,418
INCOME BEFORE INCOME TAXES	453,966	374,053	955,718	732,314
Income taxes	183,012	106,451	376,015	252,517
CONSOLIDATED NET INCOME	$270,954	$267,602	$579,703	$479,797
Earnings per average common share:
Basic	$1.42	$1.36	$3.02	$2.41
Diluted	$1.37	$1.32	$2.93	$2.34
Dividends declared per common share	$0.75	$0.54	$1.50	$1.08
Basic average number of common shares outstanding	191,326,928	196,979,140	191,983,266	198,754,673
Diluted average number of common shares outstanding	197,864,459	203,423,646	198,101,863	204,785,090
See Notes to Financial Statements.

21

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2008 and 2007
(Unaudited)
	2008	2007
	(In Thousands)
OPERATING ACTIVITIES
Consolidated net income	$579,703	$479,797
Adjustments to reconcile consolidated net income to net cash flow
provided by operating activities:
Reserve for regulatory adjustments	(2,808)	8,038
Other regulatory charges - net	69,519	36,885
Depreciation, amortization, and decommissioning	585,774	550,973
Deferred income taxes, investment tax credits, and non-current taxes accrued	365,337	507,929
Equity in earnings of unconsolidated equity affiliates - net of dividends	3,501	(2,101)
Changes in working capital:
Receivables	(216,810)	(123,088)
Fuel inventory	(12,257)	(10,533)
Accounts payable	357,503	(137,102)
Taxes accrued	-	(189,410)
Interest accrued	(48,799)	(29,093)
Deferred fuel	(555,444)	37,705
Other working capital accounts	(218,001)	(169,775)
Provision for estimated losses and reserves	10,680	56,241
Changes in other regulatory assets	39,964	132,989
Other	(44,293)	(185,323)
Net cash flow provided by operating activities	913,569	964,132
INVESTING ACTIVITIES
Construction/capital expenditures	(778,818)	(717,115)
Allowance for equity funds used during construction	18,371	24,717
Nuclear fuel purchases	(217,487)	(219,328)
Proceeds from sale/leaseback of nuclear fuel	152,353	124,185
Proceeds from sale of assets and businesses	30,725	13,063
Payment for purchase of plant	(56,409)	(336,211)
Insurance proceeds received for property damages	63,088	82,081
Changes in transition charge account	9,171	-
NYPA value sharing payment	(72,000)	-
Decrease (increase) in other investments	(95,166)	73,969
Proceeds from nuclear decommissioning trust fund sales	748,181	1,013,414
Investment in nuclear decommissioning trust funds	(809,653)	(1,075,084)
Net cash flow used in investing activities	(1,007,644)	(1,016,309)
See Notes to Financial Statements.

22

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2008 and 2007
(Unaudited)
	2008	2007
	(In Thousands)
FINANCING ACTIVITIES
Proceeds from the issuance of:
Long-term debt	1,800,543	2,042,123
Common stock and treasury stock	27,862	53,706
Retirement of long-term debt	(1,383,393)	(699,906)
Repurchase of common stock	(369,612)	(825,460)
Redemption of preferred stock	-	(2,250)
Changes in credit line borrowings - net	150,000	-
Dividends paid:
Common stock	(288,172)	(215,472)
Preferred stock	(10,030)	(13,344)
Net cash flow provided by (used in) financing activities	(72,802)	339,397
Effect of exchange rates on cash and cash equivalents	(430)	(243)
Net increase (decrease) in cash and cash equivalents	(167,307)	286,977
Cash and cash equivalents at beginning of period	1,253,728	1,016,152
Effect of the reconsolidation of Entergy New Orleans on cash and cash equivalents	-	17,093
Cash and cash equivalents at end of period	$1,086,421	$1,320,222
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized	$340,077	$297,229
Income taxes	$127,856	$228,750
See Notes to Financial Statements.

23

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
June 30, 2008 and December 31, 2007
(Unaudited)
	2008	2007
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$168,624	$126,652
Temporary cash investments - at cost,
which approximates market	917,797	1,127,076
Total cash and cash equivalents	1,086,421	1,253,728
Securitization recovery trust account	10,102	19,273
Accounts receivable:
Customer	755,425	610,724
Allowance for doubtful accounts	(20,357)	(25,789)
Other	310,645	303,060
Accrued unbilled revenues	347,163	288,076
Total accounts receivable	1,392,876	1,176,071
Deferred fuel costs	500,498	-
Accumulated deferred income taxes	-	38,117
Fuel inventory - at average cost	220,841	208,584
Materials and supplies - at average cost	725,176	692,376
Deferred nuclear refueling outage costs	194,736	172,936
System agreement cost equalization	215,869	268,000
Gas hedge contracts	122,971	- -
Prepayments and other	268,505	129,162
TOTAL	4,737,995	3,958,247
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	76,959	78,992
Decommissioning trust funds	3,154,962	3,307,636
Non-utility property - at cost (less accumulated depreciation)	224,536	220,204
Other	176,500	82,563
TOTAL	3,632,957	3,689,395
PROPERTY, PLANT AND EQUIPMENT
Electric	33,650,605	32,959,022
Property under capital lease	738,492	740,095
Natural gas	297,622	300,767
Construction work in progress	1,026,306	1,054,833
Nuclear fuel under capital lease	429,414	361,502
Nuclear fuel	609,426	665,620
TOTAL PROPERTY, PLANT AND EQUIPMENT	36,751,865	36,081,839
Less - accumulated depreciation and amortization	15,457,574	15,107,569
PROPERTY, PLANT AND EQUIPMENT - NET	21,294,291	20,974,270
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
SFAS 109 regulatory asset - net	615,832	595,743
Other regulatory assets	2,932,336	2,971,399
Deferred fuel costs	168,122	168,122
Goodwill	377,172	377,172
Other	934,636	908,654
TOTAL	5,028,098	5,021,090
TOTAL ASSETS	$34,693,341	$33,643,002
See Notes to Financial Statements.

24

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND SHAREHOLDERS' EQUITY
June 30, 2008 and December 31, 2007
(Unaudited)
	2008	2007
	(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt	$397,527	$996,757
Notes payable	175,037	25,037
Accounts payable	1,388,805	1,031,300
Customer deposits	298,632	291,171
Accumulated deferred income taxes	118,061	-
Interest accrued	139,162	187,968
Deferred fuel costs	- -	54,947
Obligations under capital leases	151,721	152,615
Pension and other postretirement liabilities	35,765	34,795
System agreement cost equalization	215,909	268,000
Fair value of derivative instruments	363,957	60,025
Other	167,654	154,139
TOTAL	3,452,230	3,256,754
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	6,306,393	6,379,679
Accumulated deferred investment tax credits	334,552	343,539
Obligations under capital leases	287,641	220,438
Other regulatory liabilities	576,601	490,323
Decommissioning and asset retirement cost liabilities	2,575,683	2,489,061
Accumulated provisions	144,875	133,406
Pension and other postretirement liabilities	1,299,857	1,361,326
Long-term debt	10,755,654	9,728,135
Fair value of derivative instruments	370,374	26,964
Other	955,657	1,039,544
TOTAL	23,607,287	22,212,415
Commitments and Contingencies
Preferred stock without sinking fund	311,019	311,162
SHAREHOLDERS' EQUITY
Common stock, $.01 par value, authorized 500,000,000
shares; issued 248,174,087 shares in 2008 and in 2007	2,482	2,482
Paid-in capital	4,860,481	4,850,769
Retained earnings	7,027,630	6,735,965
Accumulated other comprehensive income (loss)	(510,958)	8,320
Less - treasury stock, at cost (57,633,453 shares in 2008 and
55,053,847 shares in 2007)	4,056,830	3,734,865
TOTAL	7,322,805	7,862,671
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$34,693,341	$33,643,002
See Notes to Financial Statements.

25

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF RETAINED EARNINGS, COMPREHENSIVE INCOME, AND PAID-IN CAPITAL
For the Three Months Ended June 30, 2008 and 2007
(Unaudited)
	2008		2007
	(In Thousands)
RETAINED EARNINGS
Retained Earnings - Beginning of period	$6,900,345		$6,211,617
Add: Consolidated net income	270,954	$270,954	267,602	$267,602
Deduct:
Dividends declared on common stock	143,669		106,532
Retained Earnings - End of period	$7,027,630		$6,372,687
ACCUMULATED OTHER COMPREHENSIVE LOSS
Balance at beginning of period:
Accumulated derivative instrument fair value changes	($191,306)		($64,111)
Pension and other postretirement liabilities	(111,281)		(105,431)
Net unrealized investment gains	89,061		108,547
Foreign currency translation	6,377		6,435
Total	(207,149)		(54,560)
Net derivative instrument fair value changes
arising during the period (net of tax expense (benefit) of ($160,474) and $1,851)	(285,280)	(285,280)	4,549	4,549
Pension and other postretirement liabilities (net of tax expense of $348 and $1,092)	2,247	2,247	(339)	(339)
Net unrealized investment gains (losses) (net of tax expense (benefit) of ($7,901) and $4,317)	(21,223)	(21,223)	8,350	8,350
Foreign currency translation (net of tax expense of $241 and $124)	447	447	231	231
Balance at end of period:
Accumulated derivative instrument fair value changes	(476,586)		(59,562)
Pension and other postretirement liabilities	(109,034)		(105,770)
Net unrealized investment gains	67,838		116,897
Foreign currency translation	6,824		6,666
Total	($510,958)		($41,769)
Comprehensive Income (Loss)		($32,855)		$280,393
PAID-IN CAPITAL
Paid-in Capital - Beginning of period	$4,853,837		$4,831,803
Add:
Common stock issuances related to stock plans	6,644		9,256
Paid-in Capital - End of period	$4,860,481		$4,841,059
See Notes to Financial Statements.

26

ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF RETAINED EARNINGS, COMPREHENSIVE INCOME, AND PAID-IN CAPITAL
For the Six Months Ended June 30, 2008 and 2007
(Unaudited)
	2008		2007
	(In Thousands)
RETAINED EARNINGS
Retained Earnings - Beginning of period	$6,735,965		$6,113,042
Add:
Consolidated net income	579,703	$579,703	479,797	$479,797
Adjustment related to FIN 48 implementation	-		(4,600)
Total	579,703		475,197
Deduct:
Dividends declared on common stock	288,038		215,552
Retained Earnings - End of period	$7,027,630		$6,372,687
ACCUMULATED OTHER COMPREHENSIVE LOSS
Balance at beginning of period:
Accumulated derivative instrument fair value changes	($12,540)		($105,578)
Pension and other postretirement liabilities	(107,145)		(105,909)
Net unrealized investment gains	121,611		104,551
Foreign currency translation	6,394		6,424
Total	8,320		(100,512)
Net derivative instrument fair value changes
arising during the period (net of tax expense (benefit) of ($259,574) and $30,176)	(464,046)	(464,046)	46,016	46,016
Pension and other postretirement liabilities (net of tax expense of $4,325 and $1,366)	(1,889)	(1,889)	139	139
Net unrealized investment gains (losses) (net of tax expense (benefit) of ($34,531) and $7,107)	(53,773)	(53,773)	12,346	12,346
Foreign currency translation (net of tax expense of $232 and $130)	430	430	242	242
Balance at end of period:
Accumulated derivative instrument fair value changes	(476,586)		(59,562)
Pension and other postretirement liabilities	(109,034)		(105,770)
Net unrealized investment gains	67,838		116,897
Foreign currency translation	6,824		6,666
Total	($510,958)		($41,769)
Comprehensive Income		$60,425		$538,540
PAID-IN CAPITAL
Paid-in Capital - Beginning of period	$4,850,769		$4,827,265
Add (Deduct):
Common stock issuances related to stock plans	9,712		13,794
Paid-in Capital - End of period	$4,860,481		$4,841,059
See Notes to Financial Statements.

27

ENTERGY CORPORATION AND SUBSIDIARIES
SELECTED OPERATING RESULTS
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended		Increase/
Description	2008	2007	(Decrease)	%
	(Dollars in Millions)
Utility Electric Operating Revenues:
Residential	$808	$691	$117	17
Commercial	661	576	85	15
Industrial	739	640	99	15
Governmental	59	54	5	9
Total retail	2,267	1,961	306	16
Sales for resale	108	98	10	10
Other	149	136	13	10
Total	$2,524	$2,195	$329	15
Utility Billed Electric Energy
Sales (GWh):
Residential	7,372	6,985	387	6
Commercial	6,688	6,481	207	3
Industrial	9,730	9,814	(84)	(1)
Governmental	586	562	24	4
Total retail	24,376	23,842	534	2
Sales for resale	1,440	1,428	12	1
Total	25,816	25,270	546	2
Non-Utility Nuclear:
Operating Revenues	$610	$472	$138	29
Billed Electric Energy Sales (GWh)	10,145	8,896	1,249	14
	Six Months Ended		Increase/
Description	2008	2007	(Decrease)	%
	(Dollars in Millions)
Utility Electric Operating Revenues:
Residential	$1,539	$1,435	$104	7
Commercial	1,209	1,132	77	7
Industrial	1,345	1,273	72	6
Governmental	113	105	8	8
Total retail	4,206	3,945	261	7
Sales for resale	196	189	7	4
Other	168	172	(4)	(2)
Total	$4,570	$4,306	$264	6
Utility Billed Electric Energy
Sales (GWh):
Residential	15,384	14,777	607	4
Commercial	12,926	12,597	329	3
Industrial	19,107	19,137	(30)	- -
Governmental	1,155	1,111	44	4
Total retail	48,572	47,622	950	2
Sales for resale	2,729	3,066	(337)	(11)
Total	51,301	50,688	613	1
Non-Utility Nuclear:
Operating Revenues	$1,290	$930	$360	39
Billed Electric Energy Sales (GWh)	20,905	17,211	3,694	21

28

ENTERGY CORPORATION AND SUBSIDIARIES

NOTES TO FINANCIAL STATEMENTS
(Unaudited)

NOTE 1. COMMITMENTS AND CONTINGENCIES

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While management is unable to predict the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy's results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K, the Entergy Texas Form 10, and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and the Entergy Texas Form 10, and in Note 10 to the financial statements herein.

Nuclear Insurance

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

Conventional Property Insurance

See Note 8 to the financial statements in the Form 10-K and Note 6 to the financial statements in the Entergy Texas Form 10 for information regarding Entergy's non-nuclear property insurance program. In April 2008, Entergy received from its primary insurer $53.6 million of additional insurance proceeds on its Hurricane Katrina claim, and almost all of the April 2008 proceeds were allocated to Entergy New Orleans.

Entergy has settled its lawsuit against one of its excess insurers on the Hurricane Katrina claim, and in July 2008 received $71.5 million in proceeds on the claim. The July 2008 proceeds were allocated as follows: $2.0 million to Entergy Arkansas, $3.7 million to Entergy Gulf States Louisiana, $12.4 million to Entergy Louisiana, $1.8 million to Entergy Mississippi, and $48.4 million to Entergy New Orleans, with the remainder allocated in smaller amounts to other Entergy subsidiaries.

NYPA Value Sharing Agreements

Entergy's Non-Utility Nuclear business' purchase of the FitzPatrick and Indian Point 3 plants from NYPA included value sharing agreements with NYPA. In October 2007, NYPA and the subsidiaries that own the FitzPatrick and Indian Point 3 plants amended and restated the value sharing agreements to clarify and amend certain provisions of the original terms. Under the amended value sharing agreements, Entergy's Non-Utility Nuclear business agreed to make annual payments to NYPA based on the generation output of the Indian Point 3 and FitzPatrick plants from January 2007 through December 2014. Entergy's Non-Utility Nuclear business will pay NYPA $6.59 per MWh for power sold from Indian Point 3, up to an annual cap of $48 million, and $3.91 per MWh for power sold from FitzPatrick, up to an annual cap of $24 million. The annual payment for each year is due by January 15 of the following year. If Entergy or an Entergy affiliate ceases to own the plants, then, after January 2009, the annual payment obligation terminates for generation after the date that Entergy ownership ceases. We believe that the contractual obligation to make value sharing payments to NYPA, other than for 2008 generation output, will terminate if the Non-Utility Nuclear spin-off transaction is completed. On June 3, 2008, NYPA informed Entergy in writing that it disagrees with Entergy's interpretation of the termination provisions of the agreement. In addition, in regulatory proceedings in New York, the Administrative Law Judges 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 Administrative Law Judges believe should be considered by the New York Public Service Commission in making its public interest determination.

29

Employment Litigation

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

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

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos and hazardous material litigation involving Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans and see Note 6 to the financial statements in the Entergy Texas Form 10 for information regarding asbestos and hazardous material litigation involving Entergy Texas.

NOTE 2. RATE AND REGULATORY MATTERS

Regulatory Assets

Other Regulatory Assets

See Note 2 to the financial statements in the Form 10-K and in the Entergy Texas Form 10 for information regarding regulatory assets in the Utility business reflected on the balance sheets of Entergy and the Registrant Subsidiaries.

Fuel and purchased power cost recovery

See Note 2 to the financial statements in the Form 10-K for information regarding fuel proceedings involving the Utility operating companies. Following are updates to that information.

Entergy Arkansas

Production Cost Allocation Rider

In its June 2007 decision on Entergy Arkansas' August 2006 rate filing, the APSC approved a production cost allocation rider for recovery from customers of the retail portion of the costs allocated to Entergy Arkansas as a result of the System Agreement proceedings, but set a termination date of December 31, 2008 for the rider. In December 2007, the APSC issued a subsequent order stating the production cost allocation rider will remain in effect, and any future termination of the rider will be subject to eighteen months advance notice by the APSC, which would occur following notice and hearing. On March 18, 2008, the Arkansas attorney general and the AEEC filed a notice of appeal of the December 2007 APSC order. The Arkansas attorney general's and the AEEC's appeal briefs are due September 5, 2008, and the appellees' briefs, including Entergy Arkansas', are due October 5, 2008.

In June 2008, Entergy Arkansas filed with the APSC its annual redetermination of the production cost allocation rider. The redetermination resulted in a slight increase in the rates beginning with the first billing cycle of July 2008.

See Entergy Corporation and Subsidiaries' "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends - Federal Regulation - System Agreement Proceedings" in the Form 10-K and herein for a discussion of the System Agreement proceedings.

30

Energy Cost Recovery Rider

Entergy Arkansas' retail rates include an energy cost recovery rider. In December 2007, the APSC issued an order stating that Entergy Arkansas' energy cost recovery rider will remain in effect, and any future termination of the rider will be subject to eighteen months advance notice by the APSC, which would occur following notice and hearing. On March 18, 2008, the Arkansas attorney general and the AEEC filed a notice of appeal of the December 2007 APSC order. The Arkansas attorney general's and the AEEC's appeal briefs are due September 5, 2008, and the appellees' briefs, including Entergy Arkansas', are due October 5, 2008.

In March 2008, Entergy Arkansas filed with the APSC its annual energy cost rate for the period April 2008 through March 2009. The filed energy cost rate increased from $0.01179/kWh to $0.01869/kWh. The increase was caused by the following: 1) all three of the nuclear power plants from which Entergy Arkansas obtains power, ANO 1 and 2 and Grand Gulf, will have refueling outages in 2008, and the energy cost rate is adjusted to account for the replacement power costs that will be incurred while these units are down; 2) Entergy Arkansas has a deferred fuel cost balance from under-recovered fuel costs at December 31, 2007; and 3) fuel and purchased power prices have increased.

Entergy Mississippi

In May 2008, Entergy Mississippi filed its quarterly fuel adjustment factor for the third quarter 2008, effective beginning with July 2008 bills. The third quarter 2008 factor is $0.038861/kWh, which is an increase from the $0.010878/kWh factor for the second quarter 2008. The increase is due to a significant increase in fuel prices, and Entergy Mississippi has gone from an over-recovery to an under-recovery position during 2008. In July 2008, the MPSC began a proceeding to investigate the fuel procurement practices and fuel adjustment schedules of the Mississippi utility companies, including Entergy Mississippi. A two-day public hearing was held in July 2008, and after a recess as the MPSC reviewed information, the hearing resumed on August 5, 2008 for additional testimony by an expert witness retained by the MPSC. The expert witness presented testimony regarding a review of the utilities' fuel adjustment clauses.  The MPSC stated that the goal of the proceeding is fact-find ing so that the MPSC may decide whether to amend the current fuel cost recovery process.

Entergy Texas

In January 2008, Entergy Texas made a compliance filing with the PUCT describing how its 2007 Rough Production Cost Equalization receipts under the System Agreement were allocated between Entergy Gulf States, Inc.'s Texas and Louisiana jurisdictions. Several parties have intervened in the proceeding. A hearing was held at the end of July 2008, and a decision is pending.

In October 2007, Entergy Texas filed a request with the PUCT to refund $45.6 million, including interest, of fuel cost recovery over-collections through September 2007. In January 2008, Entergy Texas filed with the PUCT a stipulation and settlement agreement among the parties that updated the over-collection balance through November 2007 and establishes a refund amount, including interest, of $71 million. The PUCT approved the agreement in February 2008. The refund was made over a two-month period beginning February 2008, but was reduced by $10.3 million of under-recovered incremental purchased capacity costs. Amounts refunded through the interim fuel refund are subject to final reconciliation in a future fuel reconciliation proceeding.

Storm Cost Recovery Filings

See Note 2 to the financial statements in the Form 10-K for information regarding storm cost recovery filings involving the Utility operating companies. The following is an update to the Form 10-K.

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Entergy Gulf States Louisiana and Entergy Louisiana - Act 55 Storm Cost Financings

In March 2008, Entergy Gulf States Louisiana, Entergy Louisiana, and the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, filed at the LPSC an application requesting that the LPSC grant financing orders authorizing the financing of Entergy Gulf States Louisiana and Entergy Louisiana storm costs, storm reserves, and issuance costs pursuant to Act 55 of the Louisiana Legislature (Act 55 financings). The Act 55 financings are expected to produce additional customer benefits as compared to Act 64 traditional securitization.  Entergy Gulf States Louisiana and Entergy Louisiana also filed an application requesting LPSC approval for ancillary issues including the mechanism to flow charges and savings to customers via a Storm Cost Offset rider.  On April 3, 2008, the Louisiana State Bond Commission granted preliminary approval for the Act 55 financings.  On April 8, 2008, the Louisiana Public Facilities Authority (LPFA), which is the issuer of the bonds pursuant to the Act 55 financings, approved requests for the Act 55 financings.  On April 10, 2008, Entergy Gulf States Louisiana and Entergy Louisiana and the LPSC Staff filed with the LPSC an uncontested stipulated settlement that includes Entergy Gulf States Louisiana and Entergy Louisiana's proposals under the Act 55 financings, which includes a commitment to pass on to customers a minimum of $10 million and $30 million of customer benefits, respectively.  On April 16, 2008, the LPSC approved the settlement and issued two financing orders and one ratemaking order intended to facilitate implementation of the Act 55 financings.  On May 6, 2008, the State Bond Commission voted to approve the Act 55 financings.

On July 29, 2008, the LPFA issued $679 million in bonds under the aforementioned Act 55.  From the bond proceeds received by Entergy Louisiana from the LURC, Entergy Louisiana invested $527 million in affiliate securities.  The LURC deposited $152 million in a restricted escrow account as a storm damage reserve for Entergy Louisiana.  As approved by the April 16, 2008 LPSC orders, Entergy Louisiana withdrew $17.8 million from the restricted escrow account and also invested this amount in affiliate securities.

Entergy Gulf States Louisiana expects that in September 2008 the LPFA will issue $273 million in bonds under the aforementioned Act 55.  From the bond proceeds expected to be received by Entergy Gulf States Louisiana from the LURC, Entergy Gulf States Louisiana is expected to invest $186 million in affiliate securities.  In addition, Entergy Gulf States Louisiana expects the LURC to deposit $87 million to a restricted escrow account as a storm damage reserve for Entergy Gulf States Louisiana.  As approved by the April 16, 2008 LPSC orders, it is expected that Entergy Gulf States Louisiana will withdraw $1.7 million from the restricted escrow account and will also invest this amount in affiliate securities.

Retail Rate Proceedings

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

Filings with the APSC (Entergy Arkansas)

Ouachita Acquisition

Entergy Arkansas filed with the APSC in September 2007 for its approval of the Ouachita plant acquisition, including full cost recovery.  The APSC Staff and the Arkansas attorney general supported Entergy Arkansas' acquisition of the plant, but oppose the sale of one-third of the capacity and energy to Entergy Gulf States Louisiana.  The industrial group AEEC opposes Entergy Arkansas' purchase of the plant.  The Arkansas attorney general opposes recovery of the non-fuel costs of the plant through a separate rider, while the APSC Staff recommended revisions to the rider. In December 2007, the APSC issued an order approving recovery through a rider of the capacity costs associated with the interim tolling agreement, which will be in effect until APSC action on the acquisition of the plant. A hearing before the APSC was held in April 2008 to address Entergy Arkansas' request for acquisition of the plant and concurrent cost recovery. In June 2008 the A PSC approved Entergy Arkansas' acquisition of the Ouachita plant and approved recovery of the acquisition and ownership costs through a rate rider. The APSC also approved the planned sale of one-third of the capacity and energy to Entergy Gulf States Louisiana. The Arkansas attorney general, the AEEC, and Entergy Arkansas have

32

requested rehearing of the APSC order. Entergy Arkansas' request for rehearing concerns the 7.61% before-tax return on rate base approved by the APSC, which reflects significant sources of zero-cost capital already reflected in base rates. Entergy Arkansas had requested a 10.87% before-tax return on rate base reflecting the cost of the debt and equity capital resources available to finance the Ouachita plant acquisition.

On March 18, 2008 the Arkansas attorney general and the AEEC filed a notice of appeal of the December 2007 APSC order that approved recovery through a rider of the capacity costs associated with the interim tolling agreement. The Arkansas attorney general's and the AEEC's appeal briefs are due September 20, 2008, and the appellees' briefs, including Entergy Arkansas', are due October 20, 2008.

Storm Cost Recovery Proposal

In June 2008, together with other Arkansas utilities, Entergy Arkansas filed a joint application for approval of storm cost recovery accounting and a storm damage rider. To enable recovery of 2008 storm cost expenditures through the rider and storm reserve accounting, the applicants requested that the APSC establish a procedural schedule that would allow resolution of this proceeding no later than December 15, 2008.

Filings with the LPSC

Retail Rates - Electric

(Entergy Louisiana)

In May 2008, Entergy Louisiana made its formula rate plan filing with the LPSC for the 2007 test year, seeking an $18.4 million rate increase, comprised of $12.6 million of recovery of incremental and deferred capacity costs and $5.8 million related to lost contribution to fixed costs associated with the loss of customers due to Hurricane Katrina. The filing includes two alternative versions of the calculated revenue requirement, one that reflects Entergy Louisiana's full request for recovery of the loss of fixed cost contribution and the other that reflects the anticipated rate implementation in September 2008, subject to refund, of only a portion of the full request, with the remainder deferred, until the lost fixed cost contribution issue is resolved. Under the first alternative, Entergy Louisiana's earned return on common equity was 9.44%, whereas under the other alternative, its earned return on common equity was 9.04%. The LPSC staff and intervenors iss ued their reports on Entergy Louisiana's filing on July 31, 2008 and, with minor exceptions, primarily raised proposed disallowance issues that were previously raised with regard to Entergy Louisiana's May 2007 filing and remain at issue in that proceeding. Entergy Louisiana disagrees with the majority of the proposed adjustments.

In May 2007, Entergy Louisiana made its formula rate plan filing with the LPSC for the 2006 test year, indicating a 7.6% earned return on common equity. That filing included Entergy Louisiana's request to recover $39.8 million in unrecovered fixed costs associated with the loss of customers that resulted from Hurricane Katrina, a request that was recently reduced to $31.7 million. In September 2007, Entergy Louisiana modified its formula rate plan filing to reflect its implementation of certain adjustments proposed by the LPSC Staff in its review of Entergy Louisiana's original filing with which Entergy Louisiana agreed, and to reflect its implementation of an $18.4 million annual formula rate plan increase comprised of (1) a $23.8 million increase representing 60% of Entergy Louisiana revenue deficiency, and (2) a $5.4 million decrease for reduced incremental and deferred capacity costs. The LPSC authorized Entergy Louisiana to defer for accounting purposes the difference between i ts $39.8 million claim, now at $31.7 million, for unrecovered fixed cost and 60% of the revenue deficiency to preserve Entergy Louisiana's right to pursue that claim in full during the formula rate plan proceeding. In October 2007, Entergy Louisiana implemented a $7.1 million formula rate plan decrease that was due primarily to the reclassification of certain franchise fees from base rates to collection via a line item on customer bills pursuant to an LPSC Order. The LPSC staff and intervenors have recommended disallowance of certain costs included in Entergy Louisiana's filing. Entergy Louisiana disagrees with the majority of the proposed disallowances and a hearing on the disputed issues is set to begin in late September 2008.

33

In May 2006, Entergy Louisiana made its formula rate plan filing with the LPSC for the 2005 test year. Entergy Louisiana modified the filing in August 2006 to reflect a 9.45% return on equity which is within the allowed bandwidth. The modified filing includes an increase of $24.2 million for interim recovery of storm costs from Hurricanes Katrina and Rita and a $119.2 million rate increase to recover LPSC-approved incremental deferred and ongoing capacity costs. The filing requested recovery of approximately $50 million for the amortization of capacity deferrals over a three-year period, including carrying charges, and approximately $70 million for ongoing capacity costs. The increase was implemented, subject to refund, with the first billing cycle of September 2006. Entergy Louisiana subsequently updated its formula rate plan rider to reflect adjustments proposed by the LPSC Staff with which it agrees. The adjusted return on equity of 9.56% remains within the allowed bandwidth. Ongoing and deferred incremental capacity costs were reduced to $118.7 million. The updated formula rate plan rider was implemented, subject to refund, with the first billing cycle of October 2006. An uncontested stipulated settlement was filed in February 2008 that will leave the current base rates in place, and the LPSC approved the settlement in March 2008. In the settlement Entergy Louisiana agreed to credit customers $7.2 million, plus $0.7 million of interest, for customer contributions to the Central States Compact in Nebraska that was never completed and agreed to a one-time $2.6 million deduction from the deferred capacity cost balance. The credit, for which Entergy Louisiana had previously recorded a provision, was made in May 2008.

(Entergy Gulf States Louisiana)

In May 2008, Entergy Gulf States Louisiana made its formula rate plan filing with the LPSC for the 2007 test year. The filing reflected a 9.26% return on common equity, which is below the allowed earnings bandwidth, and indicated a $5.4 million revenue deficiency, offset by a $4.1 million decrease in required additional capacity costs. Consideration of the filing is pending, and under the formula rate plan Entergy Gulf States Louisiana would implement new rates in September 2008.

In May 2007, Entergy Gulf States Louisiana made its formula rate plan filing with the LPSC for the 2006 test year. The filing reflected a 10.0% return on common equity, which is within the allowed earnings bandwidth, and an anticipated formula rate plan decrease of $23 million annually attributable to adjustments outside of the formula rate plan sharing mechanism related to capacity costs and the anticipated securitization of storm costs related to Hurricane Katrina and Hurricane Rita and the securitization of a storm reserve. In September 2007, Entergy Gulf States Louisiana modified the formula rate plan filing to reflect a 10.07% return on common equity, which is still within the allowed bandwidth. The modified filing also reflected implementation of a $4.1 million rate increase, subject to refund, attributable to recovery of additional LPSC-approved incremental deferred and ongoing capacity costs. The rate decrease anticipated in the original filing did not occur because of the additional capacity costs approved by the LPSC, and because securitization of storm costs associated with Hurricane Katrina and Hurricane Rita and the establishment of a storm reserve have not yet occurred. In October 2007, Entergy Gulf States Louisiana implemented a $16.4 million formula rate plan decrease that is due to the reclassification of certain franchise fees from base rates to collection via a line item on customer bills pursuant to an LPSC order. The LPSC staff issued its final report in December 2007, indicating a $1.6 million decrease in formula rate plan revenues for which interim rates were already in effect. In addition, the LPSC staff recommended that the LPSC give a one-year extension of Entergy Gulf States Louisiana's formula rate plan to synchronize with the final year of Entergy Louisiana's formula rate plan, or alternatively, to extend the formula rate plan for a longer period. Entergy Gulf States Louisiana indicated it is amenable to a one-year extension. An uncontested stipul ated settlement was filed in February 2008 that will leave the current base rates in place and extend the formula rate plan for one year, and the LPSC approved the settlement in March 2008.

Retail Rates - Gas (Entergy Gulf States Louisiana)

In January 2008, Entergy Gulf States Louisiana filed with the LPSC its gas rate stabilization plan for the test year ending September 30, 2007.  The filing showed a revenue deficiency of $3.7 million based on a return on common equity mid-point of 10.5%. Entergy Gulf States Louisiana implemented a $3.4 million rate increase in April 2008 pursuant to an uncontested agreement with the LPSC staff.

34

Filings with the PUCT and Texas Cities

Entergy Texas made a rate filing in September 2007 with the PUCT requesting an annual rate increase totaling $107.5 million, including a base rate increase of $64.3 million and riders totaling $43.2 million. The base rate increase includes a $12.2 million annual increase for the storm damage reserve. Entergy Texas requested an 11% return on common equity. In December 2007 the PUCT issued an order setting September 26, 2008 as the effective date for the rate change from the rate filing. In May 2008, Entergy Texas and certain parties in the rate case filed a non-unanimous settlement that provides for a $42.5 million base rate increase beginning in October 2008 and an additional $17 million base rate increase beginning in October 2009. The non-unanimous settlement also provides that $25 million of System Agreement rough production cost equalization payments will offset the effect on customers of the rate increase. The non-unanimous settlement further provides tha t an additional $17 million on an annual basis of System Agreement rough production cost equalization payments will be retained by Entergy Texas from January 2009 through September 2009. The non-unanimous settlement also resolves the fuel reconciliation portion of the proceeding with a $4.5 million disallowance. The PUCT staff, the Texas Industrial Energy Consumers (TIEC), and the state of Texas did not join in the settlement and filed a separate agreement among them that provides for a rate decrease, later revised to a slight increase, and a $4.7 million fuel cost disallowance. In May 2008 the ALJs issued an order stating that the proceeding will continue with Entergy Texas having the burden of proof to show that the non-unanimous settlement results in reasonable rates. The hearing on the merits of the non-unanimous settlement was held from June 23 through July 2, 2008, and post-hearing briefing by the parties is ongoing.

Filings with the MPSC

In March 2008, Entergy Mississippi made its annual scheduled formula rate plan filing for the 2007 test year with the MPSC.  The filing showed that a $10.1 million increase in annual electric revenues is warranted. In June 2008, Entergy Mississippi reached a settlement with the Mississippi Public Utilities Staff that results in a $3.8 million rate increase. An MPSC decision on the settlement is pending.

Filings with the New Orleans City Council

Retail Rates

In January 2008, Entergy New Orleans voluntarily implemented a 6.15% base rate credit (the recovery credit) for electric customers, which Entergy New Orleans estimates will return approximately $10.6 million to electric customers in 2008. Entergy New Orleans was able to implement this credit because during 2007 the recovery of New Orleans after Hurricane Katrina was occurring faster than expected in 2006 projections. In addition, Entergy New Orleans committed to set aside $2.5 million for an energy efficiency program focused on community education and outreach and weatherization of homes.

On July 31, 2008, Entergy New Orleans filed an electric and gas base rate case with the City Council. The filing requests an 11.75% return on common equity. The filing calls for a $23.0 million decrease in electric base rates, which includes keeping the recovery credit in effect, as well as realigning approximately $12.3 million of capacity costs from recovery through the fuel adjustment clause to electric base rates. The filing also calls for a $9.1 million increase in gas base rates to fund on-going operations. This request is unrelated to the on-going rebuild of Entergy New Orleans' natural gas system. The procedural schedule calls for a hearing on the filing to commence on January 5, 2009, with certification of the evidentiary record by a hearing officer on or before February 28, 2009.

Fuel Adjustment Clause Litigation

See Note 2 to the financial statements in the Form 10-K for a discussion of the complaint filed in April 1999 by a group of ratepayers against Entergy New Orleans, Entergy Corporation, Entergy Services, and Entergy Power in state court in Orleans Parish purportedly on behalf of all Entergy New Orleans ratepayers and a corresponding complaint filed with the City Council. In February 2004, the City Council approved a resolution that resulted in a refund to customers of $11.3 million, including interest, during the months of June through September 2004. In May 2005 the Civil District Court

35

for the Parish of Orleans affirmed the City Council resolution, finding no support for the plaintiffs' claim that the refund amount should be higher. In June 2005, the plaintiffs appealed the Civil District Court decision to the Louisiana Fourth Circuit Court of Appeal. On February 25, 2008, the Fourth Circuit Court of Appeal issued a decision affirming in part, and reversing in part, the Civil District Court's decision.  Although the Fourth Circuit Court of Appeal did not reverse any of the substantive findings and conclusions of the City Council or the Civil District Court, the Fourth Circuit found that the amount of the refund was arbitrary and capricious and increased the amount of the refund to $34.3 million.  Entergy New Orleans believes that the increase in the refund ordered by the Fourth Circuit is not justified. Entergy New Orleans, the City Council, and the plaintiffs requested rehearing, and in April 2008, the Fourth Circuit granted the plaintiffs' request for rehearing. In addition to changing the basis for the court's decision in the manner requested by the plaintiffs, the court also granted the plaintiffs' request that it provide for interest on the refund amount. The court denied the motions for rehearing filed by the City Council and Entergy New Orleans. In May 2008, Entergy New Orleans and the City Council filed with the Louisiana Supreme Court applications for a writ of certiorari seeking, among other things, reversal of the Fourth Circuit decision.

System Energy Rate Proceeding

In March 2008, the LPSC filed a complaint at the FERC under Federal Power Act section 206 against System Energy and Entergy Services. The complaint requests that the FERC set System Energy's rate of return on common equity at no more than 9.75%. The LPSC's complaint further requests that System Energy base its decommissioning and depreciation expenses on a 60-year useful life for Grand Gulf as opposed to the 40-year life specified in the existing NRC operating license. The APSC, the City of New Orleans, the MPSC, and other parties have intervened in the proceeding. System Energy filed its answer to the complaint in April 2008, in which it denies the allegations of the LPSC and requests that the FERC dismiss the complaint without a hearing. On July 1, 2008, the FERC issued an order denying the relief requested by the LPSC.

Electric Industry Restructuring in Texas

Refer to Note 2 to the financial statements in the Form 10-K and Entergy Texas Form 10 for a discussion of electric industry restructuring activity that involves Entergy Texas.

NOTE 3. COMMON EQUITY

Common Stock

Earnings per Share

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

		For the Three Months Ended June 30,
		2008		2007
		(In Millions, Except Per Share Data)
			$/share		$/share
Consolidated net income		$271.9		$267.6
Average number of common shares outstanding - basic		191.3	$1.42	197.0	$1.36
Average dilutive effect of:
	Stock Options	5.0	(0.036)	5.1	(0.034)
	Equity Units	1.6	(0.011)	1.2	(0.008)
	Deferred Units	-	(0.000)	0.1	(0.001)
Average number of common shares outstanding - diluted		197.9	$1.37	203.4	$1.32

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		For the Six Months Ended June 30,
		2008		2007
		(In Millions, Except Per Share Data)
			$/share		$/share
Consolidated net income		$580.6		$479.8
Average number of common shares outstanding - basic		192.0	$3.02	198.8	$2.41
Average dilutive effect of:
	Stock Options	4.8	(0.073)	5.0	(0.059)
	Equity Units	1.3	(0.021)	0.9	(0.011)
	Deferred Units	-	(0.001)	0.1	(0.001)
Average number of common shares outstanding - diluted		198.1	$2.93	204.8	$2.34

Entergy's stock option and other equity compensation plans are discussed in Note 12 to the consolidated financial statements in the Form 10-K.

Treasury Stock

During the six months ended June 30, 2008, Entergy Corporation issued 687,693 shares of its previously repurchased common stock to satisfy stock option exercises and other stock-based awards. Also, during the six months ended June 30, 2008, Entergy Corporation purchased 3,267,299 shares of common stock for a total purchase price of $369.6 million.

Retained Earnings

On July 28, 2008, Entergy Corporation's Board of Directors declared a common stock dividend of $0.75 per share, payable on September 2, 2008 to holders of record as of August 8, 2008.

Accumulated Other Comprehensive Income (Loss)

Based on market prices as of June 30, 2008, cash flow hedges with net unrealized losses of approximately $233.2 million net-of-tax at June 30, 2008 are expected to be reclassified from accumulated other comprehensive income to operating revenues during the next twelve months. The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices. See Note 1 (Derivative Financial Instruments and Commodity Derivatives)and Note 16 to the financial statements in the Form 10-K for additional discussion of the accounting treatment of cash flow hedges.

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

Entergy Corporation has in place a credit facility that expires in August 2012 and has a borrowing capacity of $3.5 billion. Entergy Corporation also has the ability to issue letters of credit against the total borrowing capacity of the credit facility. The facility fee is currently 0.09% of the commitment amount. Facility fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation. The weighted average interest rate as of June 30, 2008 was 3.002% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of June 30, 2008.

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Capacity	Borrowings	Letters of Credit	Capacity Available
(In Millions)
$3,500	$2,772	$72	$656

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

Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, and Entergy Texas each had credit facilities available as of June 30, 2008 as follows:

Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of June 30, 2008
Entergy Arkansas	April 2009	$100 million (b)	4.50%	$100 million
Entergy Gulf States Louisiana	August 2012	$100 million (c)	5.00%	$30 million
Entergy Louisiana	August 2012	$200 million (d)	2.91%	$200 million
Entergy Mississippi	May 2009	$30 million (e)	3.926%	$30 million
Entergy Mississippi	May 2009	$20 million (e)	3.926%	$20 million
Entergy Texas	August 2012	$100 million (f)	2.9075%	-

(a)	The interest rate is the weighted average interest rate as of June 30, 2008 applied or that would be applied to the outstanding borrowings under the facility.
(b)	The credit facility requires Entergy Arkansas to maintain a debt ratio of 65% or less of its total capitalization.
(c)	The credit facility allows Entergy Gulf States Louisiana to issue letters of credit against the borrowing capacity of the facility. As of June 30, 2008, no letters of credit were outstanding. The credit facility requires Entergy Gulf States Louisiana to maintain a consolidated debt ratio of 65% or less of its total capitalization. Pursuant to the terms of the credit agreement, the amount of debt assumed by Entergy Texas ($930 million as of June 30, 2008 and $1.079 billion as of December 31, 2007) is excluded from debt and capitalization in calculating the debt ratio.
(d)	The credit facility allows Entergy Louisiana to issue letters of credit against the borrowing capacity of the facility. As of June 30, 2008, no letters of credit were outstanding. The credit facility requires Entergy Louisiana to maintain a consolidated debt ratio of 65% or less of its total capitalization.
(e)	Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable.
(f)	The credit facility allows Entergy Texas to issue letters of credit against the borrowing capacity of the facility. As of June 30, 2008, no letters of credit were outstanding. The credit facility requires Entergy Texas to maintain a consolidated debt ratio of 65% or less of its total capitalization. Pursuant to the terms of the credit agreement, the transition bonds issued by Entergy Gulf States Reconstruction Funding I, LLC, a subsidiary of Entergy Texas, are excluded from debt and capitalization in calculating the debt ratio.

The facility fees on the credit facilities range from 0.09% to 0.15% of the commitment amount.

The short-term borrowings of the Registrant Subsidiaries and certain other Entergy subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits are effective through March 31, 2010 (except Entergy Gulf States Louisiana and Entergy Texas, which are effective through November 8, 2009). In addition to borrowings from commercial banks, these companies are authorized under a FERC order to borrow from the Entergy System money pool. The money pool is an inter-company borrowing arrangement designed to reduce Entergy's subsidiaries' dependence on external short-term borrowings. Borrowings from the money pool and external borrowings combined may not exceed the FERC authorized limits. As of June 30, 2008, Entergy's subsidiaries' aggregate money pool and external short-term borrowings authorized limit was $2.1

38

billion, the aggregate outstanding borrowing from the money pool was $403 million, and Entergy's subsidiaries' had $380 million in outstanding short-term borrowing from external sources.

The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings for the Registrant Subsidiaries as of June 30, 2008:

	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$125.5
Entergy Gulf States Louisiana	$200	-
Entergy Louisiana	$250	$52.4
Entergy Mississippi	$175	$50.0
Entergy New Orleans	$100	-
Entergy Texas	$200	-
System Energy	$200	-

Debt Issuances and Redemptions

(Entergy Arkansas)

In July 2008, Entergy Arkansas issued $300 million of 5.4% Series First Mortgage Bonds due August 2013. Entergy Arkansas intends to use the proceeds to fund the purchase of, and improvements relating to, the Ouachita power plant and for general corporate purposes. Pending the application of the net proceeds, Entergy Arkansas intends to use the proceeds for working capital purposes, including repayment of short-term debt, and it may invest them in temporary cash investments or the Entergy System money pool.

(Entergy Gulf States Louisiana)

In May 2008, Entergy Gulf States Louisiana issued $375 million of 6.00% Series First Mortgage Bonds due May 2018. The proceeds were used to pay at maturity the portion of the $325 million of the 3.6% Series First Mortgage Bonds due June 2008 that had not been assumed by Entergy Texas and to redeem, prior to maturity, $189.7 million of the $350 million Floating Rate series of First Mortgage Bonds due December 2008, and for other general corporate purposes.

The portion of the $325 million of 3.6% Series First Mortgage Bonds due June 2008 that had been assumed by Entergy Texas was paid at maturity by Entergy Texas in June 2008, and that bond series is no longer outstanding. The remainder of the $350 million Floating Rate series of First Mortgage Bonds due December 2008 had been assumed by Entergy Texas, and management expects Entergy Texas to redeem those bonds by their maturity date.

(Entergy Louisiana)

In April 2008, Entergy Louisiana repurchased, prior to maturity, $60 million of Auction Rate governmental bonds, which are being held for possible remarketing at a later date.

(Entergy Mississippi)

In April 2008, Entergy Mississippi repurchased its $30 million series of Independence County Pollution Control Revenue Bonds due July 2022. At the time of repurchase, the bonds were converted from an Auction Rate mode to a Daily Mode. In June 2008, Entergy Mississippi remarketed the series and converted the bonds to a Multi-Annual Mode and fixed the rate to maturity at 4.90%. Entergy Mississippi used the proceeds from the remarketing to repay short-term borrowings that were drawn on its credit facilities to repurchase the bonds in April 2008.

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(Entergy New Orleans)

On August 1, 2008, Entergy New Orleans paid, at maturity, its $30 million of 3.875% Series first mortgage bonds.

Tax Exempt Bond Audit

The IRS completed an audit of certain Tax Exempt Bonds (Bonds) issued by St. Charles Parish, State of Louisiana (the Issuer). The Bonds were issued to finance previously unfinanced acquisition costs expended by Entergy Louisiana to acquire certain radioactive solid waste disposal facilities (the Facilities) at the Waterford Steam Electric Generating Station. In March and April 2005, the IRS issued proposed adverse determinations that the Issuer's 7.0% Series bonds due 2022, 7.5% Series bonds due 2021, and 7.05% Series bonds due 2022 were not tax exempt. The stated basis for these determinations was that radioactive waste did not constitute "solid waste" within the provisions of the Internal Revenue Code and therefore the Facilities did not qualify as solid waste disposal facilities. The three series of Bonds are the only series of bonds issued by the Issuer for the benefit of Entergy Louisiana that were the subject of audits by the IRS. Because the Issuer, Entergy Louisiana, and IRS O ffice of Appeals desired to settle the issue that was raised, Entergy Louisiana made a $1.25 million payment to the IRS. The terms of the settlement have no effect on the Issuer or the bondholders.

NOTE 5. STOCK-BASED COMPENSATION

Entergy grants stock options, which are described more fully in Note 12 to the consolidated financial statements in the Form 10-K. Entergy adopted SFAS 123R, "Share-Based Payment" on January 1, 2006. The adoption of the standard did not materially affect Entergy's financial position, results of operations, or cash flows because Entergy adopted the fair value based method of accounting for stock options prescribed by SFAS 123, "Accounting for Stock-Based Compensation" on January 1, 2003. Prior to 2003, Entergy applied the recognition and measurement principles of APB Opinion 25, "Accounting for Stock Issued to Employees," and related Interpretations in accounting for those plans. Awards under Entergy's plans generally vest over three years.

The following table includes financial information for stock options for the second quarter and six months ended June 30 for each of the years presented:

	2008	2007
	(In Millions)
Compensation expense included in Entergy's Net Income for the second quarter	$4.7	$3.9
Tax benefit recognized in Entergy's Net Income for the second quarter	$1.8	$1.5
Compensation expense included in Entergy's Net Income for the six months ended June 30,	$9.1	$7.1
Tax benefit recognized in Entergy's Net Income for the six months ended June 30,	$3.5	$2.7
Compensation cost capitalized as part of fixed assets and inventory	$1.7	$1.2

Entergy granted 1,617,400 stock options during the first quarter 2008 with a weighted-average fair value of $14.43. At June 30, 2008, there were 11,464,959 stock options outstanding with a weighted-average exercise price of $65.49. The aggregate intrinsic value of the stock options outstanding was $631 million.

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NOTE 6. RETIREMENT AND OTHER POSTRETIREMENT BENEFITS

Components of Net Pension Cost

Entergy's qualified pension cost, including amounts capitalized, for the second quarters of 2008 and 2007, included the following components:

	2008	2007
	(In Thousands)
Service cost - benefits earned during the period	$22,598	$24,141
Interest cost on projected benefit obligation	51,646	46,292
Expected return on assets	(57,640)	(50,880)
Amortization of prior service cost	1,266	1,383
Amortization of loss	6,482	11,444
Net pension costs	$24,352	$32,380

Entergy's qualified pension cost, including amounts capitalized, for the six months ended June 30, 2008 and 2007, included the following components:

	2008	2007
	(In Thousands)
Service cost - benefits earned during the period	$45,196	$48,038
Interest cost on projected benefit obligation	103,293	92,154
Expected return on assets	(115,279)	(101,506)
Amortization of prior service cost	2,532	2,766
Amortization of loss	13,416	22,888
Net pension costs	$49,158	$64,340

The Registrant Subsidiaries' qualified pension cost, including amounts capitalized, for the second quarters of 2008 and 2007, included the following components:

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy	System
2008	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas	Energy
	(In Thousands)
Service cost - benefits earned
during the period	$3,584	$1,841	$2,058	$1,063	$445	$968	$930
Interest cost on projected
benefit obligation	11,616	5,047	6,784	3,627	1,415	3,882	1,937
Expected return on assets	(11,765)	(7,165)	(8,134)	(4,075)	(1,839)	(5,047)	(2,452)
Amortization of prior service
cost	223	110	119	90	52	80	9
Amortization of loss	2,303	115	920	485	319	156	90
Net pension cost/(income)	$5,961	($52)	$1,747	$1,190	$392	$39	$514

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		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy	System
2007	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas	Energy
	(In Thousands)
Service cost - benefits earned
during the period	$3,638	$3,011	$2,231	$1,089	$470	$1,012	$1,021
Interest cost on projected
benefit obligation	10,498	8,139	6,251	3,371	1,260	3,439	1,710
Expected return on assets	(11,009)	(10,750)	(7,808)	(3,837)	(1,446)	(4,536)	(2,136)
Amortization of prior service
cost	412	304	160	114	44	133	12
Amortization of loss	2,721	623	1,433	749	368	262	151
Net pension cost	$6,260	$1,327	$2,267	$1,486	$696	$310	$758

The Registrant Subsidiaries' qualified pension cost, including amounts capitalized, for the six months ended June 30, 2008 and 2007, included the following components:

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy	System
2008	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas	Energy
	(In Thousands)
Service cost - benefits earned
during the period	$7,168	$3,682	$4,116	$2,126	$890	$1,936	$1,860
Interest cost on projected
benefit obligation	23,232	10,094	13,568	7,254	2,830	7,764	3,874
Expected return on assets	(23,530)	(14,330)	(16,268)	(8,150)	(3,678)	(10,094)	(4,904)
Amortization of prior service
cost	446	220	238	180	104	160	18
Amortization of loss	4,606	230	1,840	970	638	312	180
Net pension cost/(income)	$11,922	($104)	$3,494	$2,380	$784	$78	$1,028

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy	System
2007	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas	Energy
	(In Thousands)
Service cost - benefits earned
during the period	$7,276	$6,022	$4,462	$2,178	$940	$2,024	$2,042
Interest cost on projected
benefit obligation	20,996	16,278	12,502	6,742	2,520	6,878	3,420
Expected return on assets	(22,018)	(21,500)	(15,616)	(7,674)	(2,892)	(9,072)	(4,272)
Amortization of prior service
cost	824	608	320	228	88	266	24
Amortization of loss	5,442	1,246	2,866	1,498	736	524	302
Net pension cost	$12,520	$2,654	$4,534	$2,972	$1,392	$620	$1,516

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Entergy recognized $4.3 million and $4.0 million in pension cost for its non-qualified pension plans in the second quarters of 2008 and 2007, respectively. Entergy recognized $8.5 million and $8.0 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2008 and 2007, respectively.

The Registrant Subsidiaries recognized the following pension cost for their non-qualified pension plans in the second quarters of 2008 and 2007:

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy
	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas
	(In Thousands)
Non-Qualified Pension Cost   Second Quarter 2008	$133	$78	$7	$54	$12	$227
Non-Qualified Pension Cost   Second Quarter 2007	$123	$317	$6	$44	$57	$231

The Registrant Subsidiaries recognized the following pension cost for their non-qualified pension plans for the six months ended June 30, 2008 and 2007:

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy
	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas
	(In Thousands)
Non-Qualified Pension Cost Six   Months Ended June 30, 2008	$266	$156	$14	$108	$24	$454
Non-Qualified Pension Cost Six   Months Ended June 30, 2007	$246	$634	$12	$88	$114	$462

Components of Net Other Postretirement Benefit Cost

Entergy's other postretirement benefit cost, including amounts capitalized, for the second quarters of 2008 and 2007, included the following components:

	2008	2007
	(In Thousands)
Service cost - benefits earned during the period	$11,800	$11,034
Interest cost on APBO	17,824	15,808
Expected return on assets	(7,027)	(6,325)
Amortization of transition obligation	957	958
Amortization of prior service cost	(4,104)	(3,959)
Amortization of loss	3,890	4,743
Net other postretirement benefit cost	$23,340	$22,259

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Entergy's other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2008 and 2007, included the following components:

	2008	2007
	(In Thousands)
Service cost - benefits earned during the period	$23,600	$21,927
Interest cost on APBO	35,648	31,494
Expected return on assets	(14,054)	(12,585)
Amortization of transition obligation	1,914	1,916
Amortization of prior service cost	(8,208)	(7,918)
Amortization of loss	7,780	9,486
Net other postretirement benefit cost	$46,680	$44,320

The Registrant Subsidiaries' other postretirement benefit cost, including amounts capitalized, for the second quarters of 2008 and 2007, included the following components:

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy	System
2008	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas	Energy
	(In Thousands)
Service cost - benefits earned
during the period	$1,706	$1,251	$1,099	$514	$295	$606	$513
Interest cost on APBO	3,443	1,917	2,187	1,141	953	1,440	531
Expected return on assets	(2,492)	-	-	(905)	(789)	(1,885)	(511)
Amortization of transition
obligation	205	84	96	88	415	66	2
Amortization of prior service
cost	(197)	146	117	(62)	90	72	(283)
Amortization of loss	1,440	494	677	534	291	357	177
Net other postretirement   benefit cost	$4,105	$3,892	$4,176	$1,310	$1,255	$656	$429

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy	System
2007	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas	Energy
	(In Thousands)
Service cost - benefits earned
during the period	$1,525	$1,547	$973	$476	$255	$500	$451
Interest cost on APBO	3,037	2,876	1,941	1,049	870	1,260	433
Expected return on assets	(2,231)	(1,697)	-	(819)	(682)	(1,697)	(470)
Amortization of transition
obligation	205	151	96	88	416	67	2
Amortization of prior service
cost	(197)	218	117	(62)	90	72	(283)
Amortization of loss	1,500	793	764	613	282	349	149
Net other postretirement   benefit cost	$3,839	$3,888	$3,891	$1,345	$1,231	$551	$282

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The Registrant Subsidiaries' other postretirement benefit cost, including amounts capitalized, for the six months ended June 30, 2008 and 2007, included the following components:

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy	System
2008	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas	Energy
	(In Thousands)
Service cost - benefits earned
during the period	$3,412	$2,502	$2,198	$1,028	$590	$1,212	$1,026
Interest cost on APBO	6,886	3,834	4,374	2,282	1,906	2,880	1,062
Expected return on assets	(4,984)	-	-	(1,810)	(1,578)	(3,770)	(1,022)
Amortization of transition
obligation	410	168	192	176	830	132	4
Amortization of prior service
cost	(394)	292	234	(124)	180	144	(566)
Amortization of loss	2,880	988	1,354	1,068	582	714	354
Net other postretirement   benefit cost	$82,10	$7,784	$8,352	$2,620	$2,510	$1,312	$858

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy	System
2007	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas	Energy
	(In Thousands)
Service cost - benefits earned
during the period	$3,050	$3,094	$1,946	$952	$510	$1,000	$902
Interest cost on APBO	6,074	5,752	3,882	2,098	1,740	2,520	866
Expected return on assets	(4,462)	(3,394)	-	(1,638)	(1,364)	(3,394)	(940)
Amortization of transition
obligation	410	302	192	176	832	134	4
Amortization of prior service
cost	(394)	436	234	(124)	180	144	(566)
Amortization of loss	3,000	1,586	1,528	1,226	564	698	298
Net other postretirement   benefit cost	$7,678	$7,776	$7,782	$2,690	$2,462	$1,102	$564

Employer Contributions

Based on current assumptions, Entergy expects to contribute $268 million to its qualified pension plans in 2008. As of the end of July 2008, Entergy had contributed $164 million to its pension plans. Therefore, Entergy presently anticipates contributing an additional $104 million to fund its qualified pension plans in 2008.

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Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans in 2008:

		Entergy
	Entergy	Gulf States	Entergy	Entergy	Entergy	Entergy	System
	Arkansas	Louisiana	Louisiana	Mississippi	New Orleans	Texas	Energy
	(In Thousands)
Expected 2008 pension   contributions	$70,863	$27,143	$ -	$19,182	$ -	$14,960	$144
Pension contributions made   through July 2008	$21,420	$21,324	$ -	$5,798	$ -	$11,752	$88
Remaining estimated pension   contributions to be made in 2008	$49,443	$5,819	$ -	$13,384	$ -	$3,208	$56

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

Based on actuarial analysis, the estimated effect of future Medicare subsidies reduced the December 31, 2007 Accumulated Postretirement Benefit Obligation (APBO) by $182 million, and reduced the second quarter 2008 and 2007 other postretirement benefit cost by $6.2 million and $6.6 million, respectively. It reduced the six months ended June 30, 2008 and 2007 other postretirement benefit cost by $12.4 million and $13.2 million, respectively.

Based on actuarial analysis, the estimated effect of future Medicare subsidies reduced the December 31, 2007 APBO, the second quarters 2008 and 2007 other postretirement benefit cost and the six months ended June 30, 2008 and 2007 other postretirement benefit cost for the Registrant Subsidiaries as follows:

		Entergy			Entergy
	Entergy	Gulf States	Entergy	Entergy	New	Entergy	System
	Arkansas	Louisiana	Louisiana	Mississippi	Orleans	Texas	Energy
	(In Thousands)
Reduction in 12/31/2007 APBO	($39,653)	($19,662)	($21,797)	($13,223)	($9,487)	($15,270)	($6,185)
Reduction in second quarter 2008
other postretirement benefit cost	($1,266)	($876)	($706)	($406)	($279)	($263)	($236)
Reduction in second quarter 2007
other postretirement benefit cost	($1,376)	($1,222)	($762)	($438)	($311)	($172)	($246)
Reduction in six months ended
June 30, 2008 other
postretirement benefit cost	($2,532)	($1,752)	($1,412)	($812)	($558)	($526)	($472)
Reduction in six months ended
June 30, 2007 other
postretirement benefit cost	($2,752)	($2,444)	($1,524)	($876)	($622)	($344)	($492)

For further information on the Medicare Act refer to Note 11 to the financial statements in the Form 10-K.

NOTE 7. BUSINESS SEGMENT INFORMATION

Entergy Corporation

Entergy's reportable segments as of June 30, 2008 are Utility and Non-Utility Nuclear. Utility generates, transmits, distributes, and sells electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and provides natural gas utility service in portions of Louisiana. Non-Utility Nuclear owns and operates six nuclear power plants and is primarily focused on selling electric power produced by those plants to wholesale

46

customers. "All Other" includes the parent company, Entergy Corporation, and other business activity, including the non-nuclear wholesale assets business and earnings on the proceeds of sales of previously-owned businesses.

Entergy's segment financial information for the second quarters of 2008 and 2007 is as follows:

	Utility	Non-Utility Nuclear*	All Other*	Eliminations	Consolidated
	(In Thousands)
2008
Operating Revenues	$2,579,303	$609,730	$82,088	($6,850)	$3,264,271
Equity in earnings of
unconsolidated equity affiliates	$-	$-	($2,572)	$-	($2,572)
Income Taxes (Benefit)	$112,421	$83,902	($13,311)	$-	$183,012
Net Income	$159,714	$143,616	($32,376)	$-	$270,954
2007
Operating Revenues	$2,238,555	$471,521	$65,817	($6,541)	$2,769,352
Equity in earnings of
unconsolidated equity affiliates	$-	$-	$477	$-	$477
Income Taxes (Benefit)	$98,460	$63,929	($55,938)	$-	$106,451
Net Income	$148,194	$108,726	$10,682	$-	$267,602

Entergy's segment financial information for the six months ended June 30, 2008 and 2007 is as follows:

	Utility	Non-Utility Nuclear*	All Other*	Eliminations	Consolidated
	(In Thousands)
2008
Operating Revenues	$4,715,633	$1,290,215	$136,889	($13,732)	$6,129,005
Equity in earnings (loss) of
unconsolidated equity affiliates	$-	$-	($3,501)	$-	($3,501)
Income Taxes (Benefit)	$196,664	$208,875	($29,524)	$-	$376,015
Net Income (Loss)	$276,861	$365,314	($62,472)	$-	$579,703
Total Assets	$26,807,661	$7,326,735	$1,984,560	($1,425,615)	$34,693,341
2007
Operating Revenues	$4,435,654	$929,772	$110,865	($12,880)	$5,463,411
Equity in earnings (loss) of
unconsolidated equity affiliates	$-	$-	$2,101	$-	$2,101
Income Taxes (Benefit)	$179,152	$148,664	($75,299)	$-	$252,517
Net Income (Loss)	$252,644	$236,896	($9,743)	$-	$479,797
Total Assets	$26,244,883	$6,654,700	$2,815,623	($2,300,479)	$33,414,727

Businesses marked with * are sometimes referred to as the "competitive businesses," with the exception of the parent company, Entergy Corporation. Eliminations are primarily intersegment activity. Almost all of Entergy's goodwill is related to the Utility segment.

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Registrant Subsidiaries

The Registrant Subsidiaries' have one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. The Registrant Subsidiaries' operations are managed on an integrated basis because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

NOTE 8. ACQUISITION

Calcasieu (Entergy Gulf States Louisiana)

In March 2008, Entergy Gulf States Louisiana purchased the Calcasieu Generating Facility, a 322 MW simple-cycle gas-fired power plant located near the city of Sulphur in southwestern Louisiana, for approximately $56.4 million from Dynegy, Inc. Entergy Gulf States Louisiana received the plant, materials and supplies, SO₂ emission allowances, and related real estate in the transaction. The FERC and the LPSC approved the acquisition.

NOTE 9. RISK MANAGEMENT AND FAIR VALUE

Fair Values

See Note 16 to the financial statements in the Form 10-K for a discussion of Entergy's and the Registrant Subsidiaries' exposure to market and commodity risks. See Note 17 to the financial statements in the Form 10-K for a discussion of Entergy's and the Registrant Subsidiaries' decommissioning trust funds.

Effective January 1, 2008, Entergy and the Registrant Subsidiaries adopted Statement of Financial Accounting Standards No. 157, "Fair Value Measurements" (SFAS 157), which defines fair value, establishes a framework for measuring fair value in GAAP, and expands disclosures about fair value measurements. SFAS 157 generally does not require any new fair value measurements. However, in some cases, the application of SFAS 157 in the future may change Entergy's and the Registrant Subsidiaries' practice for measuring and disclosing fair values under other accounting pronouncements that require or permit fair value measurements.

SFAS 157 defines fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

SFAS 157 establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. The three levels of fair value hierarchy defined in SFAS 157 are as follows:

• Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks and debt instruments.
   

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• Level 2 - Level 2 inputs are inputs other than quoted prices included in level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Level 2 inputs include the following:

• quoted prices for similar assets or liabilities in active markets;
• quoted prices for identical assets or liabilities in inactive markets;
• inputs other than quoted prices that are observable for the asset or liability; or
• inputs that are derived principally from or corroborated by observable market data by correlation or other means.

          Level 2 consists primarily of individually owned debt instruments or shares in common trusts.

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

The following table sets forth, by level within the fair value hierarchy established by SFAS 157, Entergy's assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2008. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect their placement within the fair value hierarchy levels.

	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Decommissioning trust funds	$476	$2,646	$-	$3,122
Gas hedge contracts	123	-	-	123
	$599	$2,646	$-	$3,245
Liabilities:
Power contracts	$-	$-	$734	$734

A small portion of the assets in the decommissioning trust funds are cash and cash equivalents.

The following table sets forth a reconciliation of changes in the liabilities for the fair value of derivatives classified as level 3 in the SFAS 157 fair value hierarchy (in millions):

	Second Quarter 2008	Six Months Ended June 30, 2008
Balance as of beginning of period	$288	$12
Price changes	480	676
Originated	3	77
Settlements	(37)	(31)
Balance as of June 30, 2008	$734	$734

The following table sets forth, by level within the fair value hierarchy established by SFAS 157, the Registrant Subsidaries' assets that are accounted for at fair value on a recurring basis as of June 30, 2008. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

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	Level 1	Level 2	Level 3	Total
	(In Millions)
Entergy Arkansas:
Assets:
Decommissioning trust funds	$16.1	$419.7	$-	$435.8
Entergy Gulf States Louisiana:
Assets:
Decommissioning trust funds	$15.6	$327.8	$-	$343.4
Gas hedge contracts	25.1	-	-	25.1
	$40.7	$327.8	$-	$368.5
Entergy Louisiana:
Assets:
Decommissioning trust funds	$40.0	$165.1	$-	$205.1
Gas hedge contracts	52.8	-	-	52.8
	$92.8	$165.1	$-	$257.9
Entergy Mississippi:
Assets:
Gas hedge contracts	$44.8	$-	$-	$44.8
System Energy:
Assets:
Decommissioning trust funds	$42.9	$259.6	$-	$302.5

Other Than Temporary Impairment

In the second quarter 2008 Non-Utility Nuclear recorded a $24.4 million charge to interest income resulting from the recognition of the other than temporary impairment of certain securities held in its decommissioning trust funds.

NOTE 10. INCOME TAXES

Income Tax Audits and Litigation

Entergy expects to reach a final agreement with the IRS relating to the method of allocating overhead. Under this agreement Entergy will concede certain deductions that will result in an increase to taxable income for income tax purposes of $361 million for 2005 and $240 million for 2006. Because Entergy has a consolidated net operating loss carryover into these years, this concession has the effect of reducing the consolidated net operating loss carryover. Entergy's concession will not have a material effect on the Registrant Subsidiaries' net income. Of the total increase to taxable income for income tax purposes of $601 million, the taxable income for income tax purposes of the Registrant Subsidiaries will increase as follows: Entergy Arkansas, $173 million; Entergy Gulf States Louisiana, $200 million, of which Entergy Texas is accountable for $104 million in accordance with the jurisdictional separation plan; Entergy Louisiana, $15 million; Entergy Mississippi, $89 million; Ent ergy New Orleans, $15 million; and System Energy, $20 million.

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NOTE 11. ENTERGY GULF STATES LOUISIANA AND ENTERGY TEXAS BASIS OF PRESENTATION

Effective December 31, 2007, Entergy Gulf States, Inc. completed a jurisdictional separation into two vertically integrated utility companies, one operating under the sole retail jurisdiction of the PUCT, Entergy Texas, and the other operating under the sole retail jurisdiction of the LPSC, Entergy Gulf States Louisiana. Entergy Texas now owns all Entergy Gulf States, Inc. distribution and transmission assets located in Texas, the gas-fired generating plants located in Texas, undivided 42.5% ownership shares of Entergy Gulf States, Inc.'s 70% ownership interest in Nelson 6 and 42% ownership interest in Big Cajun 2, Unit 3, which are coal-fired generating plants located in Louisiana, and other assets and contract rights to the extent related to utility operations in Texas. Entergy Gulf States Louisiana now owns all of the remaining assets that were owned by Entergy Gulf States, Inc.  On a book value basis, approximately 58.1% of the Entergy Gulf States, Inc. assets were allocated to Entergy Gulf States Louisiana and approximately 41.9% were allocated to Entergy Texas.

As the successor to Entergy Gulf States, Inc. for financial reporting purposes, Entergy Gulf States Louisiana's income statements for the three and six months ended June 30, 2007 and cash flow statement for the six months ended June 30, 2007 include the operations of Entergy Texas. Entergy Gulf States Louisiana's income statements for the three and six months ended June 30, 2008, cash flow statement for the six months ended June 30, 2008, and balance sheets as of December 31, 2007 and June 30, 2008 reflect the effects of the separation of the Texas business.

Because the jurisdictional separation was a transaction involving entities under common control, Entergy Texas recognized the assets and liabilities allocated to it at their carrying amounts in the accounts of Entergy Gulf States, Inc. at the time of the jurisdictional separation. Entergy Texas' financial statements herein report results of operations for 2007 as though the jurisdictional separation had occurred at the beginning of 2007.

NOTE 12. NEW ACCOUNTING PRONOUNCEMENTS

In March 2008 the FASB issued Statement of Financial Accounting Standards No. 161, "Disclosures about Derivative Instruments and Hedging Activities, an amendment of FASB Statement No. 133" (SFAS 161), which requires enhanced disclosures about an entity's derivative and hedging activities. SFAS 161 requires qualitative disclosures about objectives and strategies for using derivatives, quantitative disclosures about fair value amounts of and gains and losses on derivative instruments, and disclosures about credit-risk-related contingent features in derivative agreements. SFAS 161 is effective for financial statements issued for fiscal years and interim periods beginning after November 15, 2008.

__________________________________

In the opinion of the management of Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy, the accompanying unaudited financial statements contain all adjustments (consisting primarily of normal recurring accruals and reclassification of previously reported amounts to conform to current classifications) necessary for a fair statement of the results for the interim periods presented. The business of the Registrant Subsidiaries is subject to seasonal fluctuations, however, with the peak periods occurring during the third quarter. The results for the interim periods presented should not be used as a basis for estimating results of operations for a full year.

Part I, Item 4. Controls and Procedures

Disclosure Controls and Procedures

As of June 30, 2008, evaluations were performed under the supervision and with the participation of Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy Resources (individually "Registrant" and collectively the "Registrants") management, including their respective Chief Executive Officers (CEO) and Chief

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Financial Officers (CFO). The evaluations assessed the effectiveness of the Registrants' disclosure controls and procedures. Based on the evaluations, each CEO and CFO has concluded that, as to the Registrant or Registrants for which they serve as CEO or CFO, the Registrant's or Registrants' disclosure controls and procedures are effective to ensure that information required to be disclosed by each Registrant in reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in Securities and Exchange Commission rules and forms; and that the Registrant's or Registrants' disclosure controls and procedures are also effective in reasonably assuring that such information is accumulated and communicated to the Registrant's or Registrants' management, including their respective CEOs and CFOs, as appropriate to allow timely decisions regarding required disclosure.

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ENTERGY ARKANSAS, INC.

MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Second Quarter 2008 Compared to Second Quarter 2007

Net income decreased $3.1 million primarily due to a higher effective income tax rate, partially offset by higher net revenue. Also contributing to the decrease were higher taxes other than income taxes and higher depreciation and amortization expenses.

Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Net income decreased $9.2 million primarily due to higher other operation and maintenance expenses and a higher effective income tax rate, partially offset by higher net revenue and lower interest and other charges. Also contributing to the decrease were higher depreciation and amortization expenses and lower other income.

Net Revenue

Second Quarter 2008 Compared to Second Quarter 2007

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory credits. Following is an analysis of the change in net revenue comparing the second quarter 2008 to the second quarter 2007.

	Amount
	(In Millions)
2007 net revenue	$267.6
Net wholesale revenue	11.1
Rider revenue	2.3
Purchased power capacity	(3.4)
Other	2.3
2008 net revenue	$279.9

The net wholesale revenue variance is primarily due to improved results from wholesale contracts and higher sales to affiliated companies.

The rider revenue variance is due to an Energy Efficiency rider which became effective in November 2007. The establishment of the rider results in an increase in rider revenue and a corresponding increase in other operation and maintenance expense with no impact on net income. Also contributing to the variance is the capacity acquisition rider which became effective in February 2008. See Note 2 to the financial statements for discussion of the capacity acquisition rider.

The purchased power capacity variance is primarily due to higher purchased power capacity charges, including the Ouachita interim tolling agreement, partially offset by lower reserve equalization expenses.

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

Gross operating revenues increased primarily due to:

an increase of $51.6 million in production cost allocation rider revenues which became effective in July 2007 as a result of the System Agreement proceedings. As a result of the System Agreement proceedings, Entergy Arkansas also has a corresponding increase in deferred fuel expense for payments to other Entergy system companies such that there is no effect on net income. Entergy Arkansas made payments based on the 2006 test year over a seven-month period in 2007 but collections from customers are occurring over a twelve-month period. The production cost allocation rider and System Agreement proceedings are discussed in Note 2 to the financial statements in the Form 10-K;

an increase of $52.8 million in gross wholesale revenue due to an increase in the average price of energy available for resale sales and an increase in sales to affiliated customers; and

an increase of $32.3 million in fuel cost recovery revenues due to a change in the energy cost recovery rider effective April 2008. The energy cost recovery rider filings are discussed in Note 2 to the financial statements in the Form 10-K.

          Fuel and purchased power expenses increased primarily due to:

an increase of $51.6 million in deferred System Agreement payments, as discussed above;

an increase of $32.9 million in deferred fuel expense related to higher energy cost recovery rates effective April 2008, as discussed above; and

an increase in the average market price of purchased power.

Other regulatory credits decreased primarily due to increased recovery of Grand Gulf costs due to increased usage and higher rates.

Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory credits. Following is an analysis of the change in net revenue comparing the six months ended June 30, 2008 to the six months ended June 30, 2007.

	Amount
	(In Millions)
2007 net revenue	$520.9
Net wholesale revenue	14.2
Deferred fuel costs revisions	(5.8)
Purchased power capacity	(5.2)
Other	4.0
2008 net revenue	$528.1

The net wholesale revenue variance is primarily due to improved results from wholesale contracts and higher billings to affiliated companies.

The deferred fuel cost revisions variance is primarily due to the 2006 energy cost recovery true-up, made in the first quarter 2007, which increased prior year net revenue by $6.6 million.

The purchased power capacity variance is primarily due to higher purchased power capacity charges, including the Ouachita interim tolling agreement, partially offset by lower reserve equalization expenses.

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

Gross operating revenues increased primarily due to:

an increase of $109.0 million in production cost allocation rider revenues which became effective in July 2007 as a result of the System Agreement proceedings. As a result of the System Agreement proceedings, Entergy Arkansas also has a corresponding increase in deferred fuel expense for payments to other Entergy system companies such that there is no effect on net income. Entergy Arkansas made payments based on the 2006 test year over a seven-month period in 2007 but collections from customers are occurring over a twelve-month period. The production cost allocation rider and System Agreement proceedings are discussed in Note 2 to the financial statements in the Form 10-K; and

an increase of $70.7 million in gross wholesale revenue due to an increase in the average price of energy available for resale sales and an increase in sales to affiliated customers.

The increase was partially offset by a decrease of $50.8 million in fuel cost recovery revenues due to a change in the energy cost recovery rider effective April 2007. The energy cost recovery rider filings are discussed in Note 2 to the financial statements in the Form 10-K.

Fuel and purchased power expenses increased due to:

an increase of $109.0 million in deferred System Agreement payments, as discussed above; and

an increase in purchased power expense due to an increase in the average market price of purchased power and an increase in volume as a result of a refueling outage at ANO in March 2008.

The increase was partially offset by a decrease in deferred fuel expense due to a lower energy cost recovery rate.

Other regulatory credits decreased primarily due to increased recovery of Grand Gulf costs due to increased usage and higher rates.

Other Income Statement Variances

Second Quarter 2008 Compared to Second Quarter 2007

Taxes other than income taxes increased primarily due to an increase in local franchise taxes as a result of higher residential and commercial revenue and an increase in ad valorem taxes due to a higher millage rate and a higher 2008 assessment.

Depreciation and amortization expenses increased primarily due to an increase in plant in service.

Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Other operation and maintenance expenses increased primarily due to an increase of $16.4 million in storm damage charges as a result of several storms hitting Entergy Arkansas' service territory in the first quarter 2008. Entergy Arkansas discontinued regulatory storm reserve accounting beginning July 2007 as a result of the APSC order issued in Entergy Arkansas' rate case. As a result, non-capital storm expenses are charged to other operation and maintenance expenses. The increase was partially offset by a reimbursement of $7 million of costs in connection with a litigation settlement.

Depreciation and amortization expenses increased primarily due to an increase in plant in service.

Other income decreased primarily due to a revision in 2007 to the allowance for equity funds used during construction related to removal costs and a decrease in interest earned on money pool investments.

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Interest and other charges decreased primarily due to interest expense of $2.9 million recorded in the first quarter 2007 on advances from independent power producers per a FERC order and a decrease in interest accrued on the long-term DOE spent fuel obligation, partially offset by a revision to the allowance for borrowed funds used during construction related to removal costs.

Income Taxes

The effective income tax rate was 47.9% for the second quarter of 2008 and 45.3% for the six months ended June 30, 2008. The difference in the effective income tax rate for the second quarter 2008 versus the federal statutory rate of 35.0% is primarily due to book and tax differences related to utility plant items and state income taxes. The difference in the effective income tax rate for the six months ended June 30, 2008 versus the federal statutory rate of 35.0% is primarily due to book and tax differences related to utility plant items, state income taxes, and an adjustment of the federal tax reserve for prior years, partially offset by flow-through book and tax timing differences.

The effective income tax rate was 36.8% for the second quarter of 2007 and 41.3% for the six months ended June 30, 2007. The difference in the effective income tax rate for the second quarter of 2007 versus the federal statutory rate of 35.0% is primarily due to book and tax differences related to utility plant items and state income taxes, partially offset by an adjustment of the federal tax reserve for prior years and book and tax differences related to the allowance for equity funds used during construction. The difference in the effective income tax rate for the six months ended June 30, 2007 versus the federal statutory rate of 35.0% is primarily due to book and tax differences related to utility plant items and state income taxes, partially offset by a downward revision in the estimate of federal income tax expense related to tax depreciation.

Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2008 and 2007 were as follows:

		2008	2007
		(In Thousands)
Cash and cash equivalents at beginning of period		$212	$34,815
Cash flow provided by (used in):
	Operating activities	151,750	225,125
	Investing activities	(179,625)	(159,165)
	Financing activities	38,222	(33,937)
Net increase in cash and cash equivalents		10,347	32,023
Cash and cash equivalents at end of period		$10,559	$66,838

Operating Activities

Cash flow from operations decreased $73.4 million for the six months ended June 30, 2008 compared to the six months ended June 30, 2007 primarily due to decreased recovery of deferred fuel costs, an increase in income taxes paid, the timing of payments to vendors, and an increase of $10.7 million in pension contributions.

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Investing Activities

Net cash flow used in investing activities increased $20.5 million for the six months ended June 30, 2008 compared to the six months ended June 30, 2007 primarily due to an increase in fossil construction expenditures resulting from a coal plant equipment purchase in 2008.

Financing Activities

Financing activities provided $38.2 million of cash for the six months ended June 30, 2008 compared to using $33.9 million of cash for the six months ended June 30, 2007 primarily due to borrowings of $100 million on Entergy Arkansas' credit facility, partially offset by money pool activity. Decreases in Entergy Arkansas' payable to the money pool are a use of cash flow, and Entergy Arkansas' payable to the money pool decreased by $52.3 million for the six months ended June 30, 2008. The money pool is an inter-company borrowing arrangement designed to reduce Entergy's subsidiaries' need for external short-term borrowings.

Capital Structure

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

	June 30, 2008	December 31, 2007
Net debt to net capital	50.2%	49.0%
Effect of subtracting cash from debt	0.1%	0.0%
Debt to capital	50.3%	49.0%

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

Uses and Sources of Capital

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

The planned construction and other capital investments disclosure in the Form 10-K includes approximately $24 million for initial spending during the 2008-2010 period on installation of scrubbers and low NOx burners at Entergy Arkansas' White Bluff coal plant, which under current environmental regulations must be operational by September 2013. The project remains in the planning stages and has not been fully designed, but the latest conceptual cost estimate has gone up significantly from previous estimates due to increases in equipment, commodity, and labor costs. These estimates indicate that Entergy Arkansas' share of the project could cost approximately $630 million compared to the $375 million reported in the Form 10-K. Entergy Arkansas continues to review potential environmental spending needs and financing alternatives for any such spending, and future spending estimates could change based on the results of this continuing analysis.

In July 2008, Entergy Arkansas issued $300 million of 5.4% Series First Mortgage Bonds due August 2013. Entergy Arkansas intends to use the proceeds to fund the purchase of, and improvements relating to, the Ouachita power plant and for general corporate purposes. Pending the application of the net proceeds, Entergy Arkansas intends to use the proceeds for working capital purposes, including repayment of short-term debt, and it may invest them in temporary cash investments or the Entergy System money pool.

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In April 2008, Entergy Arkansas renewed its $100 million credit facility through April 2009. As of June 30, 2008, $100 million was outstanding on the credit facility.

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

June 30, 2008	December 31, 2007	June 30, 2007	December 31, 2006
(In Thousands)
($25,541)	($77,882)	$26,450	$16,109

In May 2007, $1.8 million of Entergy Arkansas' receivable from the money pool was replaced by a note receivable from Entergy New Orleans. See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Significant Factors and Known Trends

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

State and Local Rate Regulation

Ouachita Acquisition

Entergy Arkansas filed with the APSC in September 2007 for its approval of the Ouachita plant acquisition, including full cost recovery.  The APSC Staff and the Arkansas attorney general supported Entergy Arkansas' acquisition of the plant, but oppose the sale of one-third of the capacity and energy to Entergy Gulf States Louisiana.  The industrial group AEEC opposes Entergy Arkansas' purchase of the plant.  The Arkansas attorney general opposes recovery of the non-fuel costs of the plant through a separate rider, while the APSC Staff recommended revisions to the rider. In December 2007, the APSC issued an order approving recovery through a rider of the capacity costs associated with the interim tolling agreement, which will be in effect until APSC action on the acquisition of the plant. A hearing before the APSC was held in April 2008 to address Entergy Arkansas' request for acquisition of the plant and concurrent cost recovery. In June 2008 the A PSC approved Entergy Arkansas' acquisition of the Ouachita plant and approved recovery of the acquisition and ownership costs through a rate rider. The APSC also approved the planned sale of one-third of the capacity and energy to Entergy Gulf States Louisiana. The Arkansas attorney general, the AEEC, and Entergy Arkansas have requested rehearing of the APSC order. Entergy Arkansas' request for rehearing concerns the 7.61% before-tax return on rate base approved by the APSC, which reflects significant sources of zero-cost capital already reflected in base rates. Entergy Arkansas had requested a 10.87% before-tax return on rate base reflecting the cost of the debt and equity capital resources available to finance the Ouachita plant acquisition.

On March 18, 2008 the Arkansas attorney general and the AEEC filed a notice of appeal of the December 2007 APSC order that approved recovery through a rider of the capacity costs associated with the interim tolling agreement. The Arkansas attorney general's and the AEEC's appeal briefs are due September 20, 2008, and the appellees' briefs, including Entergy Arkansas', are due October 20, 2008.

Production Cost Allocation Rider

In its June 2007 decision on Entergy Arkansas' August 2006 rate filing, the APSC approved a production cost allocation rider for recovery from customers of the retail portion of the costs allocated to Entergy Arkansas as a result of the System Agreement proceedings, but set a termination date of December 31, 2008 for the rider. In December 2007, the APSC issued a subsequent order stating the production cost allocation rider will remain

58

in effect, and any future termination of the rider will be subject to eighteen months advance notice by the APSC, which would occur following notice and hearing. On March 18, 2008 the Arkansas attorney general and the AEEC filed a notice of appeal of the December 2007 APSC order. The Arkansas attorney general's and the AEEC's appeal briefs are due September 5, 2008, and the appellees' briefs, including Entergy Arkansas', are due October 5, 2008.

In June 2008, Entergy Arkansas filed with the APSC its annual redetermination of the production cost allocation rider. The redetermination resulted in a slight increase in the rates beginning with the first billing cycle of July 2008.

Energy Cost Recovery Rider

Entergy Arkansas' retail rates include an energy cost recovery rider. In December 2007, the APSC issued an order stating that Entergy Arkansas' energy cost recovery rider will remain in effect, and any future termination of the rider will be subject to eighteen months advance notice by the APSC, which would occur following notice and hearing. On March 18, 2008 the Arkansas attorney general and the AEEC filed a notice of appeal of the December 2007 APSC order. The Arkansas attorney general's and the AEEC's appeal briefs are due September 5, 2008, and the appellees' briefs, including Entergy Arkansas', are due October 5, 2008.

In March 2008, Entergy Arkansas filed with the APSC its annual energy cost rate for the period April 2008 through March 2009. The filed energy cost rate increased from $0.01179/kWh to $0.01869/kWh. The increase was caused by the following: 1) all three of the nuclear power plants from which Entergy Arkansas obtains power, ANO 1 and 2 and Grand Gulf, will have refueling outages in 2008, and the energy cost rate is adjusted to account for the replacement power costs that will be incurred while these units are down; 2) Entergy Arkansas has a deferred fuel cost balance from under-recovered fuel costs at December 31, 2007; and 3) fuel and purchased power prices have increased.

Storm Cost Recovery Proposal

In June 2008, together with other Arkansas utilities, Entergy Arkansas filed a joint application for approval of storm cost recovery accounting and a storm damage rider. To enable recovery of 2008 storm cost expenditures through the rider and storm reserve accounting, the applicants requested that the APSC establish a procedural schedule that would allow resolution of this proceeding no later than December 15, 2008.

Federal Regulation

See "System Agreement Proceedings" and "Independent Coordinator of Transmission" in the "Significant Factors and Known Trends" section of Entergy Corporation and Subsidiaries Management's Financial Discussion and Analysis for updates to the discussion in the Form 10-K.

Critical Accounting Estimates

See "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates" in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy Arkansas' accounting for nuclear decommissioning costs, unbilled revenue, and qualified pension and other postretirement benefits.

New Accounting Pronouncements

See "New Accounting Pronouncements" section of Entergy Corporation and Subsidiaries Management's Financial Discussion and Analysis for a discussion of new accounting pronouncements.

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ENTERGY ARKANSAS, INC.
INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended		Six Months Ended
	2008	2007	2008	2007
	(In Thousands)		(In Thousands)
OPERATING REVENUES
Electric	$580,462	$434,027	$1,079,835	$936,765
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale	83,703	(17,191)	167,265	120,847
Purchased power	223,318	193,089	389,842	309,495
Nuclear refueling outage expenses	7,286	7,260	14,217	14,274
Other operation and maintenance	116,547	115,203	223,671	215,058
Decommissioning	8,696	8,134	17,248	16,134
Taxes other than income taxes	22,480	16,251	38,219	36,234
Depreciation and amortization	59,066	56,764	116,303	112,829
Other regulatory credits - net	(6,435)	(9,462)	(5,392)	(14,491)
TOTAL	514,661	370,048	961,373	810,380
OPERATING INCOME	65,801	63,979	118,462	126,385
OTHER INCOME
Allowance for equity funds used during construction	1,563	1,800	3,341	7,396
Interest and dividend income	5,547	4,150	10,804	11,733
Miscellaneous - net	(722)	(601)	(1,735)	(1,805)
TOTAL	6,388	5,349	12,410	17,324
INTEREST AND OTHER CHARGES
Interest on long-term debt	18,207	19,776	36,835	39,130
Other interest - net	1,907	1,918	3,845	6,815
Allowance for borrowed funds used during construction	(749)	(767)	(1,599)	(3,510)
TOTAL	19,365	20,927	39,081	42,435
INCOME BEFORE INCOME TAXES	52,824	48,401	91,791	101,274
Income taxes	25,303	17,809	41,552	41,799
NET INCOME	27,521	30,592	50,239	59,475
Preferred dividend requirements and other	1,718	1,718	3,437	3,437
EARNINGS APPLICABLE TO
COMMON STOCK	$25,803	$28,874	$46,802	$56,038
See Notes to Financial Statements.

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ENTERGY ARKANSAS, INC.
STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2008 and 2007
(Unaudited)
	2008	2007
	(In Thousands)
OPERATING ACTIVITIES
Net income	$50,239	$59,475
Adjustments to reconcile net income to net cash flow provided by operating activities:
Reserve for regulatory adjustments	(3,010)	658
Other regulatory credits - net	(5,392)	(14,491)
Depreciation, amortization, and decommissioning	133,551	128,963
Deferred income taxes and investment tax credits, and non-current taxes
accrued	34,884	76,124
Changes in working capital:
Receivables	(273)	49,691
Fuel inventory	(8,846)	(10,150)
Accounts payable	(85,077)	198,752
Taxes accrued	- -	(37,161)
Interest accrued	(670)	(2,962)
Deferred fuel costs	38,826	46,850
Other working capital accounts	21,347	(245,647)
Provision for estimated losses and reserves	(37)	(29)
Changes in other regulatory assets	8,739	(23,273)
Other	(32,531)	(1,675)
Net cash flow provided by operating activities	151,750	225,125
INVESTING ACTIVITIES
Construction expenditures	(174,456)	(150,285)
Allowance for equity funds used during construction	3,341	7,396
Nuclear fuel purchases	(60,335)	(40,129)
Proceeds from sale/leaseback of nuclear fuel	60,377	42,220
Proceeds from nuclear decommissioning trust fund sales	104,860	14,075
Investment in nuclear decommissioning trust funds	(113,412)	(20,290)
Change in money pool receivable - net	- -	(12,152)
Net cash flow used in investing activities	(179,625)	(159,165)
FINANCING ACTIVITIES
Change in credit borrowings - net	100,000	- -
Change in money pool payable - net	(52,341)	- -
Dividends paid:
Common stock	(6,000)	(30,500)
Preferred stock	(3,437)	(3,437)
Net cash flow provided by (used in) financing activities	38,222	(33,937)
Net increase in cash and cash equivalents	10,347	32,023
Cash and cash equivalents at beginning of period	212	34,815
Cash and cash equivalents at end of period	$10,559	$66,838
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized	$36,634	$41,895
Income taxes	$36,174	$18,643
See Notes to Financial Statements.

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ENTERGY ARKANSAS, INC.
BALANCE SHEETS
ASSETS
June 30, 2008 and December 31, 2007
(Unaudited)
	2008	2007
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents	$10,559	$212
Accounts receivable:
Customer	103,694	85,414
Allowance for doubtful accounts	(15,551)	(16,649)
Associated companies	74,409	75,756
Other	92,507	124,111
Accrued unbilled revenues	82,086	68,240
Total accounts receivable	337,145	336,872
Deferred fuel costs	75,937	114,763
Fuel inventory - at average cost	29,351	20,505
Materials and supplies - at average cost	111,515	106,165
Deferred nuclear refueling outage costs	27,257	17,623
System agreement cost equalization	215,869	268,000
Prepayments and other	38,690	16,511
TOTAL	846,323	880,651
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	11,203	11,203
Decommissioning trust funds	439,344	466,348
Non-utility property - at cost (less accumulated depreciation)	1,441	1,442
Other	5,391	5,391
TOTAL	457,379	484,384
UTILITY PLANT
Electric	6,950,028	6,792,825
Property under capital lease	1,478	2,436
Construction work in progress	128,358	146,651
Nuclear fuel under capital lease	144,125	124,585
Nuclear fuel	15,713	19,548
TOTAL UTILITY PLANT	7,239,702	7,086,045
Less - accumulated depreciation and amortization	3,188,094	3,112,896
UTILITY PLANT - NET	4,051,608	3,973,149
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
SFAS 109 regulatory asset - net	99,452	93,557
Other regulatory assets	526,173	534,937
Other	32,294	33,128
TOTAL	657,919	661,622
TOTAL ASSETS	$6,013,229	$5,999,806
See Notes to Financial Statements.

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ENTERGY ARKANSAS, INC.
BALANCE SHEETS
LIABILITIES AND SHAREHOLDERS' EQUITY
June 30, 2008 and December 31, 2007
(Unaudited)
	2008	2007
	(In Thousands)
CURRENT LIABILITIES
Notes payable	$100,000	$-
Accounts payable:
Associated companies	325,278	486,201
Other	123,751	100,246
Customer deposits	60,483	57,751
Accumulated deferred income taxes	18,355	26,964
Interest accrued	16,777	17,447
Obligations under capital leases	48,805	49,738
Other	14,537	10,890
TOTAL	707,986	749,237
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	1,374,017	1,330,324
Accumulated deferred investment tax credits	53,868	55,854
Obligations under capital leases	96,798	77,283
Other regulatory liabilities	81,953	117,510
Decommissioning	522,875	505,626
Accumulated provisions	14,377	14,414
Pension and other postretirement liabilities	251,660	260,381
Long-term debt	1,316,750	1,314,525
Other	51,230	73,739
TOTAL	3,763,528	3,749,656
Commitments and Contingencies
SHAREHOLDERS' EQUITY
Preferred stock without sinking fund	116,350	116,350
Common stock, $0.01 par value, authorized 325,000,000
shares; issued and outstanding 46,980,196 shares in 2008
and 2007	470	470
Paid-in capital	588,527	588,527
Retained earnings	836,368	795,566
TOTAL	1,541,715	1,500,913
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$6,013,229	$5,999,806
See Notes to Financial Statements.

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ENTERGY ARKANSAS, INC.
SELECTED OPERATING RESULTS
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended		Increase/
Description	2008	2007	(Decrease)	%
	(Dollars In Millions)
Electric Operating Revenues:
Residential	$ 158	$ 126	$ 32	25
Commercial	109	83	26	31
Industrial	110	81	29	36
Governmental	5	4	1	25
Total retail	382	294	88	30
Sales for resale
Associated companies	115	70	45	64
Non-associated companies	44	36	8	22
Other	39	34	5	15
Total	$ 580	$ 434	$ 146	34
Billed Electric Energy
Sales (GWh):
Residential	1,551	1,523	28	2
Commercial	1,384	1,383	1	- -
Industrial	1,765	1,799	(34)	(2)
Governmental	66	67	(1)	(1)
Total retail	4,766	4,772	(6)	- -
Sales for resale
Associated companies	1,964	1,578	386	24
Non-associated companies	590	586	4	1
Total	7,320	6,936	384	6
	Six Months Ended		Increase/
Description	2008	2007	(Decrease)	%
	(Dollars In Millions)
Electric Operating Revenues:
Residential	$ 337	$ 307	$ 30	10
Commercial	203	182	21	12
Industrial	202	183	19	10
Governmental	9	9	-	- -
Total retail	751	681	70	10
Sales for resale
Associated companies	211	148	63	43
Non-associated companies	77	70	7	10
Other	41	38	3	8
Total	$ 1,080	$ 937	$ 143	15
Billed Electric Energy
Sales (GWh):
Residential	3,694	3,555	139	4
Commercial	2,731	2,711	20	1
Industrial	3,478	3,520	(42)	(1)
Governmental	131	132	(1)	(1)
Total retail	10,034	9,918	116	1
Sales for resale
Associated companies	3,918	3,571	347	10
Non-associated companies	1,130	1,255	(125)	(10)
Total	15,082	14,744	338	2

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ENTERGY GULF STATES LOUISIANA, L.L.C.

MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS

Jurisdictional Separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas

See Part I, Item 1 in the Form 10-K and Entergy Gulf States Louisiana's Management's Financial Discussion and Analysis in the Form 10-K for a discussion of the jurisdictional separation of Entergy Gulf States, Inc. into two vertically integrated utility companies, one operating under the sole retail jurisdiction of the PUCT, Entergy Texas, and the other operating under the sole retail jurisdiction of the LPSC, Entergy Gulf States Louisiana.

Entergy Gulf States Louisiana is the successor for financial reporting purposes to Entergy Gulf States, Inc. Entergy Gulf States Louisiana's Income Statement for the three and six months ended June 30, 2008 and Entergy Gulf States Louisiana's Cash Flow Statement for the six months ended June 30, 2008, reflect the effects of the separation of the Texas business. Entergy Gulf States Louisiana's Income Statement for the three and six months ended June 30, 2007 and Entergy Gulf States Louisiana's Cash Flow Statement for the six months ended June 30, 2007, include the operations of Entergy Texas. Entergy Gulf States Louisiana's balance sheets as of June 30, 2008 and December 31, 2007 reflect the effects of the separation of the Texas business.

Pursuant to the LPSC order approving the jurisdictional separation plan, Entergy Gulf States has made two compliance filings in 2008. On March 31, 2008, Entergy Gulf States Louisiana made its jurisdictional separation plan balance sheet compliance filing with the LPSC. On June 11, 2008, Entergy Gulf States Louisiana made its revenue and expense compliance filing.

Results of Operations

Following are income statement variances for Entergy Gulf States Louisiana comparing the second quarter 2008 to the second quarter 2007 showing how much the line item increased or (decreased) in comparison to the prior period:

	Second Quarter 2007	Variance caused directly by the jurisdictional separation	Variance caused by other factors	Second Quarter 2008
	(In Thousands)
Net revenue (operating revenue less fuel expense,    purchased power, and other regulatory    charges/credits)	$308,654	($90,646)	($11,086)	$206,922
Other operation and maintenance expenses	141,275	(47,239)	(2,549)	91,487
Taxes other than income taxes	34,830	(12,871)	(2,556)	19,403
Depreciation and amortization	53,060	(17,346)	(1,606)	34,108
Other expenses	6,718	(43)	4,509	11,184
Other income	18,578	4,759	(3,754)	19,583
Interest charges	36,634	(3,259)	(1,880)	31,495
Income taxes	22,755	(5,291)	(1,823)	15,641
Net Income (Loss)	$31,960	$162	($8,935)	$23,187

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Following are income statement variances for Entergy Gulf States Louisiana comparing the six months ended June 30, 2008 to the six months ended June 30, 2007 showing how much the line item increased or (decreased) in comparison to the prior period:

	Six months ended June 30, 2007	Variance caused directly by the jurisdictional separation	Variance caused by other factors	Six months ended June 30, 2008
	(In Thousands)
Net revenue (operating revenue less fuel expense,    purchased power, and other regulatory    charges/credits)	$587,107	($166,220)	($18,475)	$402,412
Other operation and maintenance expenses	267,129	(89,190)	(6,975)	170,964
Taxes other than income taxes	66,142	(26,004)	(3,453)	36,685
Depreciation and amortization	105,475	(34,480)	(3,761)	67,234
Other expenses	13,217	(85)	4,790	17,922
Other income	39,383	8,768	(4,995)	43,156
Interest charges	73,983	(8,233)	(2,744)	63,006
Income taxes	40,987	(3,018)	(2,225)	35,744
Net Income (Loss)	$59,557	$3,558	($9,102)	$54,013

Net Income

Second Quarter 2008 Compared to Second Quarter 2007

Net income decreased by $8.8 million primarily due to lower net revenue, other than the effect on net revenue directly caused by the jurisdictional separation.

Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Net income decreased by $5.5 million primarily due to lower net revenue, other than the effect on net revenue directly caused by the jurisdictional separation, partially offset by lower other operation and maintenance expenses and the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007. For the six months ended June 30, 2007, Entergy Texas reported a net loss of $3.6 million.

Net Revenue

Second Quarter 2008 Compared to Second Quarter 2007

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses and 3) other regulatory charges (credits). Following is an analysis of the change in net revenue comparing the second quarter 2008 to the second quarter 2007.

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	Amount
	(In Millions)
2007 net revenue	$308.7
Jurisdictional separation	(90.6)
Volume/weather	11.1
Other	(22.3)
2008 net revenue	$206.9

Net revenue decreased primarily due to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007.

The volume/weather variance is due to increased electricity usage in the residential and commercial sectors primarily as a result of more favorable weather compared to the same period in 2007 and increased electricity sales during the unbilled sales period. Billed retail electricity usage increased a total of 91 GWh in the residential and commercial sectors. See Note 1 to the financial statements in the Form 10-K for a discussion of the accounting for unbilled revenues.

The Other variance is primarily caused by various operational effects of the jurisdictional separation on revenues and fuel and purchased power expenses.

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

Gross operating revenues decreased primarily due to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007, partially offset by an increase in fuel cost recovery revenues due to higher fuel rates and increased usage.

Fuel and purchased power expense decreased primarily due to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007.

Other regulatory charges decreased primarily due to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007 and a decrease in capacity charges.

Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses and 3) other regulatory charges. Following is an analysis of the change in net revenue comparing six months ended June 30, 2008 to the six months ended June 30, 2007.

	Amount
	(In Millions)
2007 net revenue	$587.1
Jurisdictional separation	(166.2)
Volume/weather	10.5
Other	(29.0)
2008 net revenue	$402.4

Net revenue decreased primarily due to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007.

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The volume/weather variance is due to increased electricity usage in the residential and commercial sectors primarily as a result of more favorable weather compared to the same period in 2007. Billed retail electricity usage increased a total of 119 GWh for the residential and commercial sectors.

The Other variance is primarily caused by various operational effects of the jurisdictional separation on revenues and fuel and purchased power expenses.

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

Gross operating revenues decreased primarily due to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007, partially offset by an increase in fuel cost recovery revenues due to higher fuel rates and increased usage.

Fuel and purchased power expense decreased primarily due to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007.

Other regulatory charges decreased primarily due to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007 and a decrease in capacity charges.

Other Income Statement Variances

Second Quarter 2008 Compared to Second Quarter 2007

Other operation and maintenance decreased primarily due to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007.

Taxes other than income taxes decreased primarily due to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007.

Depreciation and amortization decreased primarily due to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007.

Nuclear refueling outage expenses increased due to the amortization of higher expenses associated with the planned maintenance and refueling outage at River Bend in the first quarter 2008 as well as the delay of this outage from late 2007 to early 2008 resulting in a shorter amortization period for these costs.

Other income includes $15 million in interest and dividend income in 2008 related to the debt assumption agreement between Entergy Gulf States Louisiana and Entergy Texas and the $1.079 billion of debt assumed by Entergy Texas as of December 31, 2007. Entergy Gulf States Louisiana remains primarily liable on this debt. The increase in interest income is partially offset by $10 million of other income reported by Entergy Texas for the second quarter 2007. The income from the debt assumption agreement offsets the interest expense on the portion of long-term debt assumed by Entergy Texas. The remaining variance was caused by various individually insignificant factors.

Interest and other charges decreased primarily due to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007 and due to a decrease in long-term debt outstanding.

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Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Other operation and maintenance decreased primarily due to:

a decrease of $89.2 million due to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007;

a decrease of $7.9 million in nuclear labor and contract costs due to a non-refueling plant outage in March 2007; and

a decrease of $2.9 million in payroll-related costs.

The decrease was partially offset by an increase of $4.8 million in transmission spending due to higher transmission equalization expenses.

Taxes other than income taxes decreased primarily due to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007.

Depreciation and amortization decreased primarily due to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007.

Nuclear refueling outage expenses increased due to the amortization of higher expenses associated with the planned maintenance and refueling outage at River Bend in the first quarter 2008 as well as the delay of this outage from late 2007 to early 2008 resulting in a shorter amortization period for these costs.

Other income includes $30 million in interest and dividend income in 2008 related to the debt assumption agreement between Entergy Gulf States Louisiana and Entergy Texas and the $1.079 billion of debt assumed by Entergy Texas as of December 31, 2007. Entergy Gulf States Louisiana remains primarily liable on this debt. The increase in interest income is partially offset by $21 million of other income reported by Entergy Texas for the six months ended June 30, 2007. The income from the debt assumption agreement offsets the interest expense on the portion of long-term debt assumed by Entergy Texas. The remaining variance was caused by various individually insignificant factors.

Interest and other charges decreased primarily due to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007 and due to a decrease in long-term debt outstanding.

Income Taxes

The effective income tax rate was 40.3% for the second quarter 2008 and 39.8% for the six months ended June 30, 2008. The differences in the effective income tax rate for the second quarter 2008 and the six months ended June 30, 2008 versus the federal statutory rate of 35% are due to book and tax differences related to utility plant items and state income taxes, partially offset by flow-through book and tax timing differences, the amortization of investment tax credits, and book and tax differences related to allowance for equity funds used during construction.

The effective income tax rate was 41.6% for the second quarter 2007 and 40.8% for the six months ended June 30, 2007. The differences in the effective income tax rate for the second quarter 2007 and the six months ended June 30, 2007 versus the federal statutory rate of 35.0% are primarily due to book and tax differences related to utility plant items and state income taxes, partially offset by flow-through book and tax timing differences related to a pension payment, book and tax differences related to allowance for equity funds used during construction, and the amortization of investment tax credits.

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Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2008 and 2007 were as follows:

		2008	2007
		(In Thousands)
Cash and cash equivalents at beginning of period		$108,036	$180,381
Cash flow provided by (used in):
	Operating activities	107,817	245,575
	Investing activities	(176,998)	(246,690)
	Financing activities	(5,379)	272,290
Net increase (decrease) in cash and cash equivalents		(74,560)	271,175
Cash and cash equivalents at end of period		$33,476	$451,556

Operating Activities

Net cash flow provided by operating activities decreased $137.8 million for the six months ended June 30, 2008 compared to the six months ended June 30, 2007 primarily due to the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas, effective December 31, 2007 and decreased recovery of deferred fuel costs, partially offset by the timing of payments to vendors. Fuel prices have been increasing, and due to the time lag before the fuel adjustment rate increases in response, Entergy Gulf States Louisiana has under-recovered fuel costs thus far in 2008.

Investing Activities

Net cash flow used in investing activities decreased $69.7 million for the six months ended June 30, 2008 compared to the six months ended June 30, 2007 primarily due to the effect of the jurisdictional separation on money pool activity and construction expenditures. The decrease was partially offset by the purchase of the Calcasieu Generating Facility for $56.4 million and an increase in nuclear construction expenditures of $19.1 million primarily due to the rescheduling of the River Bend refueling outage from late 2007 to early 2008. See "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources" in the Form 10-K for a discussion of the Calcasieu purchase which was completed in March 2008.

Increases in Entergy Gulf States Louisiana's receivable from the money pool are a use of cash flow, and Entergy Gulf States Louisiana's receivable from the money pool increased by $19.5 million the six months ended June 30, 2008 compared to increasing by $117.7 million the six months ended June 30, 2007. The money pool is an inter-company borrowing arrangement designed to reduce Entergy's subsidiaries' need for external short-term borrowings.

Financing Activities

Financing activities used $5.4 million for the six months ended June 30, 2008 compared to providing $272.3 million for the six months ended June 30, 2007 primarily due to the issuance of $329.5 million of securitization bonds in June 2007, partially offset by borrowings of $30 million on Entergy Gulf States Louisiana's credit facility.

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Capital Structure

Entergy Gulf States Louisiana's capitalization is balanced between equity and debt, as shown in the following table.The calculation below does not reduce the debt by the long-term debt assumed by Entergy Texas ($930 million as of June 30, 2008 and $1.079 billion as of December 31, 2007) because Entergy Gulf States Louisiana remains primarily liable on the debt.

	June 30, 2008	December 31, 2007
Net debt to net capital	63.9%	64.4%
Effect of subtracting cash from debt	0.3%	1.0%
Debt to capital	64.2%	65.4%

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

Uses and Sources of Capital

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

Entergy Gulf States Louisiana's receivables from the money pool were as follows:

June 30, 2008	December 31, 2007	June 30, 2007	December 31, 2006
(In Thousands)
$74,961	$55,509	$192,747	$75,048

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

As discussed in the Form 10-K, Entergy Gulf States Louisiana has a credit facility in the amount of $100 million scheduled to expire in August 2012. As of June 30, 2008, $30 million was outstanding on the credit facility.

In May 2008, Entergy Gulf States Louisiana issued $375 million of 6.00% Series First Mortgage Bonds due May 2018. The proceeds were used to pay at maturity the portion of the $325 million of 3.6% Series First Mortgage Bonds due June 2008 that had not been assumed by Entergy Texas and to redeem, prior to maturity, $189.7 million of the $350 million Floating Rate series of First Mortgage bonds due December 2008, and for other general corporate purposes.

The portion of the $325 million of 3.6% Series First Mortgage Bonds due June 2008 that had been assumed by Entergy Texas was paid at maturity by Entergy Texas in June 2008, and that bond series is no longer outstanding. The remainder of the $350 million Floating Rate series of First Mortgage bonds due December 2008 had been assumed by Entergy Texas, and management expects Entergy Texas to redeem those bonds by their maturity date.

Hurricane Rita and Hurricane Katrina

See the Form 10-K for a discussion of the effects of Hurricanes Katrina and Rita, which hit Entergy Gulf States Inc.'s jurisdictions in Louisiana and Texas in August and September 2005, which resulted in power outages, significant damage to electric distribution, transmission, and generation

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infrastructure, the temporary loss of sales and customers due to mandatory evacuations, and Entergy Gulf States, Inc.'s initiatives to recover storm restoration and business continuity costs and incremental losses.

Act 55 Storm Cost Financings

In March 2008, Entergy Gulf States Louisiana, Entergy Louisiana, and the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, filed at the LPSC an application requesting that the LPSC grant financing orders authorizing the financing of Entergy Gulf States Louisiana and Entergy Louisiana storm costs, storm reserves, and issuance costs pursuant to Act 55 of the Louisiana Legislature (Act 55 financings). The Act 55 financings are expected to produce additional customer benefits as compared to Act 64 traditional securitization.  Entergy Gulf States Louisiana and Entergy Louisiana also filed an application requesting LPSC approval for ancillary issues including the mechanism to flow charges and savings to customers via a Storm Cost Offset rider.  On April 3, 2008, the Louisiana State Bond Commission granted preliminary approval for the Act 55 financings.  On April 8, 2008, the Louisiana Public Facilities Authority (LPFA), which is the issuer of the bonds pursuant to the Act 55 financings, approved requests for the Act 55 financings.  On April 10, 2008, Entergy Gulf States Louisiana and Entergy Louisiana and the LPSC Staff filed with the LPSC an uncontested stipulated settlement that includes Entergy Gulf States Louisiana and Entergy Louisiana's proposals under the Act 55 financings, which includes a commitment to pass on to customers a minimum of $10 million and $30 million of customer benefits, respectively.  On April 16, 2008, the LPSC approved the settlement and issued two financing orders and one ratemaking order intended to facilitate implementation of the Act 55 financings.  On May 6, 2008, the State Bond Commission voted to approve the Act 55 financings.

Entergy Gulf States Louisiana expects that in September 2008 the LPFA will issue $273 million in bonds under the aforementioned Act 55.  From the bond proceeds expected to be received by Entergy Gulf States Louisiana from the LURC, Entergy Gulf States Louisiana is expected to invest $186 million in affiliate securities.  In addition, Entergy Gulf States Louisiana expects the LURC to deposit $87 million to a restricted escrow account as a storm damage reserve for Entergy Gulf States Louisiana.  As approved by the April 16, 2008 LPSC orders, it is expected that Entergy Gulf States Louisiana will withdraw $1.7 million from the restricted escrow account and will also invest this amount in affiliate securities.

Significant Factors and Known Trends

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

State and Local Rate Regulation

Retail Rates - Electric

In July 2008, the LPSC approved an uncontested settlement between Entergy Gulf States Louisiana and the LPSC Staff authorizing Entergy Gulf States Louisiana's purchase of one-third of the capacity and energy from the 789 MW Ouachita plant, which Entergy Arkansas plans to acquire in 2008. Entergy Gulf States Louisiana expects to purchase one-third of the plant's capacity and output from Entergy Arkansas under a life-of-unit agreement.

In May 2008, Entergy Gulf States Louisiana made its formula rate plan filing with the LPSC for the 2007 test year. The filing reflected a 9.26% return on common equity, which is below the allowed earnings bandwidth, and indicated a $5.4 million revenue deficiency, offset by a $4.1 million decrease in required additional capacity costs. Consideration of the filing is pending, and under the formula rate plan Entergy Gulf States Louisiana would implement new rates in September 2008.

In May 2007, Entergy Gulf States Louisiana made its formula rate plan filing with the LPSC for the 2006 test year. The filing reflected a 10.0% return on common equity, which is within the allowed earnings bandwidth, and an anticipated formula rate plan decrease of $23 million annually attributable

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to adjustments outside of the formula rate plan sharing mechanism related to capacity costs and the anticipated securitization of storm costs related to Hurricane Katrina and Hurricane Rita and the securitization of a storm reserve. In September 2007, Entergy Gulf States Louisiana modified the formula rate plan filing to reflect a 10.07% return on common equity, which is still within the allowed bandwidth. The modified filing also reflected implementation of a $4.1 million rate increase, subject to refund, attributable to recovery of additional LPSC-approved incremental deferred and ongoing capacity costs. The rate decrease anticipated in the original filing did not occur because of the additional capacity costs approved by the LPSC, and because securitization of storm costs associated with Hurricane Katrina and Hurricane Rita and the establishment of a storm reserve have not yet occurred. In October 2007, Entergy Gulf States Louisiana implemented a $16.4 million formula rate plan decr ease that is due to the reclassification of certain franchise fees from base rates to collection via a line item on customer bills pursuant to an LPSC order. The LPSC staff issued its final report in December 2007, indicating a $1.6 million decrease in formula rate plan revenues for which interim rates were already in effect. In addition, the LPSC staff recommended that the LPSC give a one-year extension of Entergy Gulf States Louisiana's formula rate plan to synchronize with the final year of Entergy Louisiana's formula rate plan, or alternatively, to extend the formula rate plan for a longer period. Entergy Gulf States Louisiana indicated it is amenable to a one-year extension. An uncontested stipulated settlement was filed in February 2008 that will leave the current base rates in place and extend the formula rate plan for one year, and the LPSC approved the settlement in March 2008.

Retail Rates - Gas

In January 2008, Entergy Gulf States Louisiana filed with the LPSC its gas rate stabilization plan for the test year ending September 30, 2007.  The filing showed a revenue deficiency of $3.7 million based on a return on common equity mid-point of 10.5%. Entergy Gulf States Louisiana implemented a $3.4 million rate increase in April 2008 pursuant to an uncontested agreement with the LPSC staff.

Federal Regulation

See "System Agreement Proceedings" and "Independent Coordinator of Transmission" in the "Significant Factors and Known Trends" section of Entergy Corporation and Subsidiaries Management's Financial Discussion and Analysis for updates to the discussion in the Form 10-K.

Critical Accounting Estimates

See "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates" in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy Gulf States Louisiana's accounting for nuclear decommissioning costs, the application of SFAS 71, unbilled revenue, and qualified pension and other postretirement benefits.

New Accounting Pronouncements

See "New Accounting Pronouncements" section of Entergy Corporation and Subsidiaries Management's Financial Discussion and Analysis for a discussion of new accounting pronouncements.

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ENTERGY GULF STATES LOUISIANA, L.L.C.
INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended		Six Months Ended
	2008	2007	2008	2007
	(In Thousands)		(In Thousands)
OPERATING REVENUES
Electric	$681,491	$864,568	$1,201,787	$1,659,822
Natural gas	21,045	17,090	59,313	55,018
TOTAL	702,536	881,658	1,261,100	1,714,840
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale	56,394	192,623	82,116	432,190
Purchased power	440,379	376,395	772,185	683,199
Nuclear refueling outage expenses	8,084	3,816	11,783	7,472
Other operation and maintenance	91,487	141,275	170,964	267,129
Decommissioning	3,100	2,902	6,139	5,745
Taxes other than income taxes	19,403	34,830	36,685	66,142
Depreciation and amortization	34,108	53,060	67,234	105,475
Other regulatory charges (credits) - net	(1,159)	3,986	4,387	12,344
TOTAL	651,796	808,887	1,151,493	1,579,696
OPERATING INCOME	50,740	72,771	109,607	135,144
OTHER INCOME
Allowance for equity funds used during construction	1,222	1,999	2,915	6,430
Interest and dividend income	19,461	15,920	42,269	32,294
Miscellaneous - net	(1,100)	659	(2,028)	659
TOTAL	19,583	18,578	43,156	39,383
INTEREST AND OTHER CHARGES
Interest on long-term debt	31,486	34,797	63,252	69,690
Other interest - net	740	3,122	1,564	8,466
Allowance for borrowed funds used during construction	(731)	(1,285)	(1,810)	(4,173)
TOTAL	31,495	36,634	63,006	73,983
INCOME BEFORE INCOME TAXES	38,828	54,715	89,757	100,544
Income taxes	15,641	22,755	35,744	40,987
NET INCOME	23,187	31,960	54,013	59,557
Preferred distribution requirements and other	207	929	413	1,891
EARNINGS APPLICABLE TO COMMON EQUITY	$22,980	$31,031	$53,600	$57,666
See Notes to Financial Statements.

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ENTERGY GULF STATES LOUISIANA, L.L.C.
STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2008 and 2007
(Unaudited)
	2008	2007
	(In Thousands)
OPERATING ACTIVITIES
Net income	$54,013	$59,557
Adjustments to reconcile net income to net cash flow provided by operating activities:
Reserve for regulatory adjustments	-	11,534
Other regulatory charges - net	4,387	12,344
Depreciation, amortization, and decommissioning	73,373	111,220
Deferred income taxes, investment tax credits, and non-current taxes accrued	77,410	(11,844)
Changes in working capital:
Receivables	(74,624)	(171,125)
Fuel inventory	(3,458)	(14,410)
Accounts payable	81,767	40,920
Taxes accrued	-	(12,913)
Interest accrued	(376)	58
Deferred fuel costs	(65,694)	25,258
Other working capital accounts	(98,852)	133,953
Provision for estimated losses and reserves	1,398	(1,163)
Changes in other regulatory assets	(935)	10,539
Other	59,408	51,647
Net cash flow provided by operating activities	107,817	245,575
INVESTING ACTIVITIES
Construction expenditures	(100,924)	(139,892)
Allowance for equity funds used during construction	2,915	6,430
Insurance proceeds	-	6,580
Nuclear fuel purchases	(21,807)	(7,542)
Proceeds from sale/leaseback of nuclear fuel	21,755	9,923
Payment for purchase of plant	(56,409)	-
Proceeds from nuclear decommissioning trust fund sales	26,318	29,533
Investment in nuclear decommissioning trust funds	(33,328)	(36,404)
Change in money pool receivable - net	(19,452)	(117,699)
Changes in other investments - net	3,934	2,381
Net cash flow used in investing activities	(176,998)	(246,690)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	369,549	321,938
Retirement of long-term debt	(366,681)	-
Redemption of preferred stock	-	(2,250)
Changes in credit borrowing - net	30,000	-
Dividends/distributions paid:
Common equity	(37,800)	(45,500)
Preferred membership interests	(447)	(1,898)
Net cash flow provided by (used in) financing activities	(5,379)	272,290
Net increase (decrease) in cash and cash equivalents	(74,560)	271,175
Cash and cash equivalents at beginning of period	108,036	180,381
Cash and cash equivalents at end of period	$33,476	$451,556
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized	$63,446	$73,694
Income taxes	$11,154	$9,559
Noncash financing activities:
Repayment by Entergy Texas of assumed long-term debt	$148,837	$-
See Notes to Financial Statements.

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ENTERGY GULF STATES LOUISIANA, L.L.C.
BALANCE SHEETS
ASSETS
June 30, 2008 and December 31, 2007
(Unaudited)
	2008	2007
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$86	$233
Temporary cash investments - at cost,
which approximates market	33,390	107,803
Total cash and cash equivalents	33,476	108,036
Accounts receivable:
Customer	88,533	62,408
Allowance for doubtful accounts	(1,259)	(979)
Associated companies	274,645	218,891
Other	63,246	59,059
Accrued unbilled revenues	62,311	54,021
Total accounts receivable	487,476	393,400
Deferred fuel costs	71,338	5,644
Accumulated deferred income taxes	- -	21,938
Fuel inventory - at average cost	35,268	31,810
Materials and supplies - at average cost	103,032	100,161
Deferred nuclear refueling outage costs	31,219	5,155
Debt assumption by Entergy Texas	160,286	309,123
Gas hedge contracts	25,089	- -
Prepayments and other	53,093	23,533
TOTAL	1,000,277	998,800
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	344,859	366,062
Non-utility property - at cost (less accumulated depreciation)	112,534	109,517
Other	12,990	17,350
TOTAL	470,383	492,929
UTILITY PLANT
Electric	6,285,221	6,132,362
Natural gas	102,463	98,484
Construction work in progress	100,379	141,528
Nuclear fuel under capital lease	122,393	110,769
Nuclear fuel	9,047	11,256
TOTAL UTILITY PLANT	6,619,503	6,494,399
Less - accumulated depreciation and amortization	3,460,471	3,433,131
UTILITY PLANT - NET	3,159,032	3,061,268
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
SFAS 109 regulatory asset - net	308,009	299,023
Other regulatory assets	330,454	335,897
Deferred fuel costs	100,124	100,124
Long-term receivables	1,311	1,872
Debt assumption by Entergy Texas	769,971	769,971
Other	19,721	12,807
TOTAL	1,529,590	1,519,694
TOTAL ASSETS	$6,159,282	$6,072,691
See Notes to Financial Statements.

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ENTERGY GULF STATES LOUISIANA, L.L.C.
BALANCE SHEETS
LIABILITIES AND MEMBERS' EQUITY
June 30, 2008 and December 31, 2007
(Unaudited)
	2008	2007
	(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt	$160,286	$675,000
Accounts payable:
Associated companies	273,316	201,217
Other	121,247	111,579
Customer deposits	39,885	38,061
Accumulated deferred income taxes	12,191	- -
Interest accrued	29,022	29,398
Obligations under capital leases	28,795	28,795
Pension and other postretirement liabilities	7,255	7,064
System agreement cost equalization	106,581	124,775
Other	9,928	9,052
TOTAL	788,506	1,224,941
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	1,268,194	1,219,568
Accumulated deferred investment tax credits	93,690	95,745
Obligations under capital leases	93,598	81,974
Other regulatory liabilities	87,111	69,890
Decommissioning and asset retirement cost liabilities	213,687	204,828
Accumulated provisions	13,285	11,887
Pension and other postretirement liabilities	88,823	102,510
Long-term debt	2,077,190	1,674,113
Other	118,999	87,468
TOTAL	4,054,577	3,547,983
Commitments and Contingencies
MEMBERS' EQUITY
Preferred membership interests without sinking fund	10,000	10,000
Members' equity	1,328,501	1,312,701
Accumulated other comprehensive loss	(22,302)	(22,934)
TOTAL	1,316,199	1,299,767
TOTAL LIABILITIES AND MEMBERS' EQUITY	$6,159,282	$6,072,691
See Notes to Financial Statements.

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ENTERGY GULF STATES LOUISIANA, L.L.C.
STATEMENTS OF MEMBERS' EQUITY AND COMPREHENSIVE INCOME
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended
	2008		2007
	(In Thousands)
MEMBERS' EQUITY
Members' Equity - Beginning of period	$1,312,933		$2,218,500
Add: Net Income	23,187	$23,187	31,960	$31,960
Deduct:
Dividends/distributions declared on common equity	7,400		11,900
Preferred membership interests	207	207	929	929
Other	12		-
	7,619		12,829
Members' Equity - End of period	$1,328,501		$2,237,631
ACCUMULATED OTHER COMPREHENSIVE
LOSS (Net of Taxes):
Balance at beginning of period:
Pension and other postretirement liabilities	($22,605)		($19,580)
Pension and other postretirement liabilities (net of tax expense of $452 and $326)	303	303	335	335
Balance at end of period:
Pension and other postretirement liabilities	($22,302)		($19,245)
Comprehensive Income		$23,283		$31,366
	Six Months Ended
	2008		2007
	(In Thousands)
MEMBERS' EQUITY
Members' Equity - Beginning of period	$1,312,701		$2,225,465
Add: Net Income	54,013	$54,013	59,557	$59,557
Deduct:
Dividends/distributions declared on common equity	37,800		45,500
Preferred membership interests	413	413	1,891	1,891
	38,213		47,391
Members' Equity - End of period	$1,328,501		$2,237,631
ACCUMULATED OTHER COMPREHENSIVE
LOSS (Net of Taxes):
Balance at beginning of period:
Pension and other postretirement liabilities	($22,934)		($19,914)
Pension and other postretirement liabilities (net of tax expense of $880 and $652)	632	632	669	669
Balance at end of period:
Pension and other postretirement liabilities	($22,302)		($19,245)
Comprehensive Income		$54,232		$58,335
See Notes to Financial Statements.

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ENTERGY GULF STATES LOUISIANA, L.L.C.
SELECTED OPERATING RESULTS
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended		Increase/
Description	2008	2007	(Decrease)	%
	(Dollars In Millions)
Electric Operating Revenues:
Residential	$131	$238	($107)	(45)
Commercial	131	208	(77)	(37)
Industrial	179	284	(105)	(37)
Governmental	6	12	(6)	(50)
Total retail	447	742	(295)	(40)
Sales for resale
Associated companies	162	39	123	315
Non-associated companies	48	52	(4)	(8)
Other	24	32	(8)	(25)
Total	$681	$865	($184)	(21)
Billed Electric Energy
Sales (GWh):
Residential	1,133	2,210	(1,077)	(49)
Commercial	1,213	2,160	(947)	(44)
Industrial	2,161	3,918	(1,757)	(45)
Governmental	53	109	(56)	(51)
Total retail	4,560	8,397	(3,837)	(46)
Sales for resale
Associated companies	1,932	481	1,451	302
Non-associated companies	671	693	(22)	(3)
Total	7,163	9,571	(2,408)	(25)
	Six Months Ended		Increase/
Description	2008	2007	(Decrease)	%
	(Dollars In Millions)
Electric Operating Revenues:
Residential	$246	$480	($234)	(49)
Commercial	242	402	(160)	(40)
Industrial	332	539	(207)	(38)
Governmental	12	23	(11)	(48)
Total retail	832	1,444	(612)	(42)
Sales for resale
Associated companies	248	66	182	276
Non-associated companies	93	102	(9)	(9)
Other	29	48	(19)	(40)
Total	$1,202	$1,660	($458)	(28)
Billed Electric Energy
Sales (GWh):
Residential	2,224	4,532	(2,308)	(51)
Commercial	2,348	4,184	(1,836)	(44)
Industrial	4,298	7,502	(3,204)	(43)
Governmental	106	221	(115)	(52)
Total retail	8,976	16,439	(7,463)	(45)
Sales for resale
Associated companies	2,678	1,234	1,444	117
Non-associated companies	1,335	1,544	(209)	(14)
Total	12,989	19,217	(6,228)	(32)
(1) Amounts for the three and six months ended June 30, 2008 reflect the effects of the separation of the Texas business. Amounts for the three and six months ended June 30, 2007 include the operations of Entergy Texas.

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ENTERGY LOUISIANA, LLC

MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Second Quarter 2008 Compared to Second Quarter 2007

Net income increased $5.7 million primarily due to higher net revenue and higher other income, partially offset by higher other operation and maintenance expenses.

Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Net income increased slightly, by $1.6 million, primarily due to higher net revenue, lower depreciation and amortization expenses, higher other income, and lower interest charges, substantially offset by higher other operation and maintenance expenses and a higher effective income tax rate.

Net Revenue

Second Quarter 2008 Compared to Second Quarter 2007

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges. Following is an analysis of the change in net revenue comparing the second quarter 2008 to the second quarter 2007.

	Amount
	(In Millions)
2007 net revenue	$246.4
Volume/weather	12.9
Other	(1.1)
2008 net revenue	$258.2

The volume/weather variance is primarily due to increased electricity usage, including the effect of more favorable weather compared to the same period in 2007. Billed retail electricity usage increased a total of 355 GWh in all sectors.

Gross operating revenues and fuel and purchased power expenses

Gross operating revenues increased primarily due to an increase of $75.9 million in fuel cost recovery revenues due to higher fuel rates and usage and an increase of $12.9 million related to volume/weather, as discussed above.

Fuel and purchased power expenses increased primarily due to increases in the average market prices of natural gas and purchased power, offset by a decrease in the recovery from customers of deferred fuel costs.

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Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges. Following is an analysis of the change in net revenue comparing the six months ended June 30, 2008 to the six months ended June 30, 2007.

	Amount
	(In Millions)
2007 net revenue	$460.8
Volume/weather	13.4
Other	3.3
2008 net revenue	$477.5

The volume/weather variance is primarily due to increased electricity usage, including the effect of more favorable weather compared to the same period in 2007. Billed retail electricity usage increased a total of 385 GWh in all sectors.

Gross operating revenues and fuel and purchased power expenses

Gross operating revenues increased primarily due to an increase of $27.4 million in fuel cost recovery revenues due to higher fuel rates and usage and an increase of $13.4 million related to volume/weather, as discussed above.

Fuel and purchased power expenses increased primarily due to increases in the average market prices of natural gas and purchased power, offset by a decrease in the recovery from customers of deferred fuel costs.

Other Income Statement Variances

Second Quarter 2008 Compared to Second Quarter 2007

Other operation and maintenance expenses increased primarily due to:

an increase of $1.4 million in payroll-related costs;

an increase of $1.2 million due to higher insurance premiums for non-nuclear property;

an increase of $1.0 million in loss reserves; and

an increase of $1.0 million in transmission spending due to additional costs related to compliance, substation maintenance, and line and vegetation maintenance.

Other income increased primarily due to interest earned on the deferred fuel balance and carrying charges on storm restoration costs approved by the LPSC.

Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Other operation and maintenance expenses increased primarily due to:

an increase of $6.9 million in fossil expenses due to a fossil plant maintenance outage in 2008;

an increase of $2.3 million due to higher insurance premiums for non-nuclear property;

an increase of $1.8 million in loss reserves; and

an increase of $1.7 million in transmission spending due to additional costs related to compliance, substation maintenance, and line and vegetation maintenance.

81

Depreciation and amortization expenses decreased primarily because Entergy Louisiana stopped recording depreciation on storm cost-related assets in the third quarter 2007. Recovery of the cost of those assets will now be through the securitization of storm costs as approved by the LPSC in the third quarter 2007. See "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Hurricane Rita and Hurricane Katrina" in the Form 10-K for a discussion of the securitization approval.

Other income increased primarily due to interest earned on the deferred fuel balance and carrying charges on storm restoration costs approved by the LPSC.

Interest charges decreased primarily due to lower interest expense on money pool borrowings and a decrease in long-term debt outstanding as a result of the repurchase of $60 million Auction Rate governmental bonds in April 2008. These bonds are being held for remarketing at a later date.

Income Taxes

The effective income tax rate was 39.7% for the second quarters of 2008 and 2007. The effective income tax rates for the six months ended June 30, 2008 and 2007 were 41.5% and 38%, respectively. The difference in the effective income tax rate for the second quarters of 2008 and 2007 and the six months ended June 30, 2008 and 2007 versus the federal statutory rate of 35.0% are primarily due to book and tax differences related to utility plant items and state income taxes, partially offset by book and tax differences related to the allowance for equity funds used during construction and the amortization of investment tax credits.

Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2008 and 2007 were as follows:

		2008	2007
		(In Thousands)
Cash and cash equivalents at beginning of period		$300	$2,743
Cash flow provided by (used in):
	Operating activities	14,596	141,156
	Investing activities	(201,257)	(130,609)
	Financing activities	186,731	(10,548)
Net increase (decrease) in cash and cash equivalents		70	(1)
Cash and cash equivalents at end of period		$370	$2,742

Operating Activities

Cash flow provided by operating activities decreased $126.6 million for the six months ended June 30, 2008 compared to the six months ended June 30, 2007 primarily due to decreased recovery of deferred fuel costs, partially offset by the timing of collections from customers, the timing of payments to vendors, and a decrease of $28.5 million in income tax payments.Fuel prices have been increasing, and due to the time lag before the fuel adjustment rate increases in response, Entergy Louisiana has under-recovered fuel costs thus far in 2008.

82

Investing Activities

Net cash flow used in investing activities increased $70.6 million for the six months ended June 30, 2008 compared to the six months ended June 30, 2007 primarily due to:

increased spending on the Little Gypsy Unit 3 repowering project;

increased spending on various nuclear projects;

timing differences between nuclear fuel payments and reimbursements from the trust that occurred in 2007; and

more insurance proceeds received in 2007 than in 2008 relating to Hurricanes Katrina and Rita.

Financing Activities

Financing activities provided cash of $186.7 million for the six months ended June 30, 2008 compared to using cash of $10.5 million for the six months ended June 30, 2007 primarily due to borrowings of $200 million on Entergy Louisiana's credit facility and money pool activity, partially offset by the repurchase, prior to maturity, of $60 million of Auction Rate governmental bonds, which are being held for remarketing at a later date. Increases in Entergy Louisiana's payable to the money pool are a source of cash flow, and Entergy Louisiana's payable to the money pool increased by $49.6 million for the six months ended June 30, 2008 compared to decreasing by $7.1 million for the six months ended June 30, 2007. The money pool is an inter-company borrowing arrangement designed to reduce Entergy's subsidiaries' need for external short-term borrowings.

Capital Structure

Entergy Louisiana's capitalization is balanced between equity and debt, as shown in the following table. The increase in the debt to capital ratio for Entergy Louisiana as of June 30, 2008 is primarily due to borrowings of $200 million on Entergy Louisiana's credit facility, partially offset by the repurchase, prior to maturity, of $60 million of Auction Rate governmental bonds.

	June 30, 2008	December 31, 2007
Net debt to net capital	46.3%	43.4%
Effect of subtracting cash from debt	-	-
Debt to capital	46.3%	43.4%

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

Uses and Sources of Capital

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

83

Entergy Louisiana's payables to the money pool were as follows:

June 30, 2008	December 31, 2007	June 30, 2007	December 31, 2006
(In Thousands)
($52,419)	($2,791)	($46,968)	($54,041)

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

As discussed in the Form 10-K, Entergy Louisiana has a credit facility in the amount of $200 million scheduled to expire in August 2012. As of June 30, 2008, $200 million was outstanding on the credit facility.

Hurricane Rita and Hurricane Katrina

See the Form 10-K for a discussion of the effects of Hurricane Katrina and Hurricane Rita and Entergy's initiatives to recover storm restoration and business continuity costs and incremental losses, which includes obtaining reimbursement of certain costs covered by insurance and pursuing recovery through existing or new rate mechanisms regulated by the FERC and local regulatory bodies, in combination with securitization. In August and September 2005, Hurricane Katrina and Hurricane Rita, along with extensive flooding that resulted from levee breaks in and around Entergy Louisiana's service territory, caused catastrophic damage.

Insurance Claims

Entergy has settled its lawsuit against one of its excess insurers on the Hurricane Katrina claim, and in July 2008 received $71.5 million in proceeds on the claim. The July 2008 proceeds were allocated as follows: $2.0 million to Entergy Arkansas, $3.7 million to Entergy Gulf States Louisiana, $12.4 million to Entergy Louisiana, $1.8 million to Entergy Mississippi, and $48.4 million to Entergy New Orleans, with the remainder allocated in smaller amounts to other Entergy subsidiaries.

Act 55 Storm Cost Financings

In March 2008, Entergy Gulf States Louisiana, Entergy Louisiana, and the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, filed at the LPSC an application requesting that the LPSC grant financing orders authorizing the financing of Entergy Gulf States Louisiana and Entergy Louisiana storm costs, storm reserves, and issuance costs pursuant to Act 55 of the Louisiana Legislature (Act 55 financings). The Act 55 financings are expected to produce additional customer benefits as compared to Act 64 traditional securitization.  Entergy Gulf States Louisiana and Entergy Louisiana also filed an application requesting LPSC approval for ancillary issues including the mechanism to flow charges and savings to customers via a Storm Cost Offset rider.  On April 3, 2008, the Louisiana State Bond Commission granted preliminary approval for the Act 55 financings.  On April 8, 2008, the Louisiana Public Facilities Authority (LPFA), which is the issuer of the bonds pursuant to the Act 55 financings, approved requests for the Act 55 financings.  On April 10, 2008, Entergy Gulf States Louisiana and Entergy Louisiana and the LPSC Staff filed with the LPSC an uncontested stipulated settlement that includes Entergy Gulf States Louisiana and Entergy Louisiana's proposals under the Act 55 financings, which includes a commitment to pass on to customers a minimum of $10 million and $30 million of customer benefits, respectively.  On April 16, 2008, the LPSC approved the settlement and issued two financing orders and one ratemaking order intended to facilitate implementation of the Act 55 financings.  On May 6, 2008, the State Bond Commission voted to approve the Act 55 financings.

On July 29, 2008, the LPFA issued $679 million in bonds under the aforementioned Act 55.  From the bond proceeds received by Entergy Louisiana from the LURC, Entergy Louisiana invested $527 million in affiliate securities.  The LURC deposited $152 million in a restricted escrow account as a storm damage reserve for Entergy Louisiana.  As approved by the April 16, 2008 LPSC orders, Entergy Louisiana withdrew $17.8 million from the restricted escrow account and also invested this amount in affiliate securities.

84

Little Gypsy Repowering Project

The preconstruction and operating air permits for the Little Gypsy repowering project were issued by the Louisiana Department of Environmental Quality (LDEQ) in November 2007 under then-effective federal and state air regulations, including the EPA's Clean Air Mercury Rule that had been issued in 2005 (CAMR 2005). As discussed in more detail in part I, Item 1, "Environmental Regulation, Clean Air Act and Subsequent Amendments, Hazardous Air Pollutants" in the Form 10-K, in February 2008 the U.S. Court of Appeals for the D.C. Circuit struck down CAMR 2005. The D.C. Circuit decision requires utilities that have not yet begun construction of the facility in question to undergo a case-by-case Maximum Achievable Control Technology (MACT) analysis for construction or reconstruction of emission units pursuant to the Clean Air Act before beginning construction. The Little Gypsy project as currently configured is expected to meet MACT standards. Little Gypsy received its construction permit bef ore a formal MACT analysis was required, however, and Entergy Louisiana has sought a MACT determination from the LDEQ. The filing was made in June 2008, and the LDEQ has certified that the filing is complete. A decision on the MACT determination is expected by first quarter 2009. Entergy Louisiana also is awaiting permit determinations from several additional agencies. These permits are unrelated to CAMR 2005 and always have been part of the construction process. Onsite construction of the project was scheduled to begin in July 2008, but obtaining the MACT determination will cause a delay in the start of construction, which Entergy Louisiana now expects to begin in mid-year 2009. This delays the expected commercial operation date of the project to mid-2013. The LPSC approved the temporary suspension of Phase II of the Little Gypsy proceedings because Entergy Louisiana must update its estimated project cost and schedule in order to support the request to recover cash earnings on its construction work i n progress costs. Entergy Louisiana plans to refile the Phase II case in September 2008, and a decision is expected in the first quarter 2009. The LPSC Phase I order has been appealed to the state district court in Baton Rouge, Louisiana by a group led by the Sierra Club and represented by the Tulane Environmental Law Clinic. A procedural schedule for the appeal has not been set.

Entergy Louisiana expects a net reduction of committed capital expenditures for 2008-2010 of approximately $210 million from the estimates disclosed in the Form 10-K as a result of delayed construction of the Little Gypsy repowering project. The delay is expected to increase the total project cost, however, from approximately $1.55 billion to $1.76 billion, primarily due to price escalation on non-contracted equipment and material and increased carrying cost due to the extended construction period.

Waterford 3 Steam Generator Replacement Project

As discussed in more detail in the Form 10-K, Entergy Louisiana plans to replace the Waterford 3 steam generators, along with the reactor vessel closure head and control element drive mechanisms, in 2011.  In June 2008, Entergy Louisiana filed with the LPSC for approval of the project, including full cost recovery. Entergy Louisiana estimates in the filing that it will spend approximately $511 million on this project. The petition seeks relief in two phases. Phase I seeks certification within 120 days that the public convenience and necessity would be served by undertaking this project. Among other relief requested, Entergy Louisiana is also seeking approval for a procedure to synchronize permanent base rate recovery when the project is placed in service, either by a formula rate plan or base rate filing. In Phase II, Entergy Louisiana will seek cash earnings on construction work in progress. A status conference was held on July 31, 2008, and a procedural schedule for Phase I wa s adopted providing for hearings in October 2008 and LPSC consideration in December 2008.

Significant Factors and Known Trends

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

85

Retail Rates

In May 2008, Entergy Louisiana made its formula rate plan filing with the LPSC for the 2007 test year, seeking an $18.4 million rate increase, comprised of $12.6 million of recovery of incremental and deferred capacity costs and $5.8 million related to lost contribution to fixed costs associated with the loss of customers due to Hurricane Katrina. The filing includes two alternative versions of the calculated revenue requirement, one that reflects Entergy Louisiana's full request for recovery of the loss of fixed cost contribution and the other that reflects the anticipated rate implementation in September 2008, subject to refund, of only a portion of the full request, with the remainder deferred, until the lost fixed cost contribution issue is resolved. Under the first alternative, Entergy Louisiana's earned return on common equity was 9.44%, whereas under the other alternative, its earned return on common equity was 9.04%. The LPSC staff and intervenors iss ued their reports on Entergy Louisiana's filing on July 31, 2008 and, with minor exceptions, primarily raised proposed disallowance issues that were previously raised with regard to Entergy Louisiana's May 2007 filing and remain at issue in that proceeding. Entergy Louisiana disagrees with the majority of the proposed adjustments.

In May 2007, Entergy Louisiana made its formula rate plan filing with the LPSC for the 2006 test year, indicating a 7.6% earned return on common equity. That filing included Entergy Louisiana's request to recover $39.8 million in unrecovered fixed costs associated with the loss of customers that resulted from Hurricane Katrina, a request that was recently reduced to $31.7 million. In September 2007, Entergy Louisiana modified its formula rate plan filing to reflect its implementation of certain adjustments proposed by the LPSC Staff in its review of Entergy Louisiana's original filing with which Entergy Louisiana agreed, and to reflect its implementation of an $18.4 million annual formula rate plan increase comprised of (1) a $23.8 million increase representing 60% of Entergy Louisiana revenue deficiency, and (2) a $5.4 million decrease for reduced incremental and deferred capacity costs. The LPSC authorized Entergy Louisiana to defer for accounting purposes the difference between i ts $39.8 million claim, now at $31.7 million, for unrecovered fixed cost and 60% of the revenue deficiency to preserve Entergy Louisiana's right to pursue that claim in full during the formula rate plan proceeding. In October 2007, Entergy Louisiana implemented a $7.1 million formula rate plan decrease that was due primarily to the reclassification of certain franchise fees from base rates to collection via a line item on customer bills pursuant to an LPSC Order. The LPSC staff and intervenors have recommended disallowance of certain costs included in Entergy Louisiana's filing. Entergy Louisiana disagrees with the majority of the proposed disallowances and a hearing on the disputed issues is set to begin in late September 2008.

In May 2006, Entergy Louisiana made its formula rate plan filing with the LPSC for the 2005 test year. Entergy Louisiana modified the filing in August 2006 to reflect a 9.45% return on equity which is within the allowed bandwidth. The modified filing includes an increase of $24.2 million for interim recovery of storm costs from Hurricanes Katrina and Rita and a $119.2 million rate increase to recover LPSC-approved incremental deferred and ongoing capacity costs. The filing requested recovery of approximately $50 million for the amortization of capacity deferrals over a three-year period, including carrying charges, and approximately $70 million for ongoing capacity costs. The increase was implemented, subject to refund, with the first billing cycle of September 2006. Entergy Louisiana subsequently updated its formula rate plan rider to reflect adjustments proposed by the LPSC Staff with which it agrees. The adjusted return on equity of 9.56% remains within the allowed bandwidth. Ongoing and deferred incremental capacity costs were reduced to $118.7 million. The updated formula rate plan rider was implemented, subject to refund, with the first billing cycle of October 2006. An uncontested stipulated settlement was filed in February 2008 that will leave the current base rates in place, and the LPSC approved the settlement in March 2008. In the settlement Entergy Louisiana agreed to credit customers $7.2 million, plus $0.7 million of interest, for customer contributions to the Central States Compact in Nebraska that was never completed and agreed to a one-time $2.6 million deduction from the deferred capacity cost balance. The credit, for which Entergy Louisiana had previously recorded a provision, was made in May 2008.

Federal Regulation

See "System Agreement Proceedings" and "Independent Coordinator of Transmission" in the "Significant Factors and Known Trends" section of Entergy Corporation and Subsidiaries Management's Financial Discussion and Analysis for updates to the discussion in the Form 10-K.

86

Critical Accounting Estimates

See "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates" in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy Louisiana's accounting for nuclear decommissioning costs, unbilled revenue, and qualified pension and other postretirement benefits.

New Accounting Pronouncements

See "New Accounting Pronouncements" section of Entergy Corporation and Subsidiaries Management's Financial Discussion and Analysis for a discussion of new accounting pronouncements.

87

ENTERGY LOUISIANA, LLC
INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended		Six Months Ended
	2008	2007	2008	2007
	(In Thousands)		(In Thousands)
OPERATING REVENUES
Electric	$753,778	$656,299	$1,318,522	$1,273,778
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale	142,279	172,762	255,274	366,718
Purchased power	342,322	226,165	564,849	423,928
Nuclear refueling outage expenses	4,222	4,418	8,725	8,615
Other operation and maintenance	111,537	104,694	212,409	196,161
Decommissioning	4,931	4,591	9,775	9,099
Taxes other than income taxes	16,507	14,962	31,248	28,776
Depreciation and amortization	47,909	49,214	94,970	98,192
Other regulatory charges - net	10,944	10,949	20,927	22,292
TOTAL	680,651	587,755	1,198,177	1,153,781
OPERATING INCOME	73,127	68,544	120,345	119,997
OTHER INCOME
Allowance for equity funds used during construction	3,765	2,309	7,022	6,257
Interest and dividend income	3,956	1,861	8,705	5,455
Miscellaneous - net	(727)	(456)	(1,939)	(1,688)
TOTAL	6,994	3,714	13,788	10,024
INTEREST AND OTHER CHARGES
Interest on long-term debt	18,777	20,350	38,332	40,583
Other interest - net	3,031	2,359	4,186	5,719
Allowance for borrowed funds used during construction	(2,308)	(1,554)	(4,304)	(4,300)
TOTAL	19,500	21,155	38,214	42,002
INCOME BEFORE INCOME TAXES	60,621	51,103	95,919	88,019
Income taxes	24,077	20,305	39,780	33,453
NET INCOME	36,544	30,798	56,139	54,566
Preferred distribution requirements and other	1,738	1,737	3,475	3,475
EARNINGS APPLICABLE TO
COMMON EQUITY	$34,806	$29,061	$52,664	$51,091
See Notes to Financial Statements.

88

ENTERGY LOUISIANA, LLC
STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2008 and 2007
(Unaudited)
	2008	2007
	(In Thousands)
OPERATING ACTIVITIES
Net income	$56,139	$54,566
Adjustments to reconcile net income to net cash flow provided by operating activities:
Reserve for regulatory adjustments	- -	(179)
Other regulatory charges - net	20,927	22,292
Depreciation, amortization, and decommissioning	104,745	107,291
Deferred income taxes, investment tax credits, and non-current taxes accrued	55,975	5,252
Changes in working capital:
Receivables	(49,797)	(108,934)
Accounts payable	134,714	(51,003)
Taxes accrued	19,130	48,577
Interest accrued	(7,248)	(23)
Deferred fuel costs	(260,114)	24,968
Other working capital accounts	(106,877)	62,853
Provision for estimated losses and reserves	2,630	(3,299)
Changes in other regulatory assets	12,824	2,466
Other	31,548	(23,671)
Net cash flow provided by operating activities	14,596	141,156
INVESTING ACTIVITIES
Construction expenditures	(203,859)	(153,715)
Allowance for equity funds used during construction	7,022	6,257
Insurance proceeds	612	10,065
Nuclear fuel purchases	(70,626)	(3,103)
Proceeds from the sale/leaseback of nuclear fuel	70,216	14,279
Changes in other investments - net	(500)	- -
Proceeds from nuclear decommissioning trust fund sales	9,293	6,423
Investment in nuclear decommissioning trust funds	(13,415)	(10,815)
Net cash flow used in investing activities	(201,257)	(130,609)
FINANCING ACTIVITIES
Additional equity from parent	- -	1,119
Retirement of long-term debt	(60,000)	- -
Changes in credit borrowing - net	200,000	- -
Change in money pool payable - net	49,628	(7,073)
Distributions paid:
Preferred membership interests	(2,897)	(4,594)
Net cash flow provided by (used in) financing activities	186,731	(10,548)
Net increase (decrease) in cash and cash equivalents	70	(1)
Cash and cash equivalents at beginning of period	300	2,743
Cash and cash equivalents at end of period	$370	$2,742
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized	$48,039	$44,328
Income taxes	$1,250	$29,736
See Notes to Financial Statements.

89

ENTERGY LOUISIANA, LLC
BALANCE SHEETS
ASSETS
June 30, 2008 and December 31, 2007
(Unaudited)
	2008	2007
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents	$370	$300
Accounts receivable:
Customer	138,458	96,679
Allowance for doubtful accounts	(1,329)	(1,988)
Associated companies	90,769	91,873
Other	9,878	14,186
Accrued unbilled revenues	88,631	75,860
Total accounts receivable	326,407	276,610
Deferred fuel costs	211,330	- -
Accumulated deferred income taxes	- -	15,229
Materials and supplies - at average cost	112,428	108,959
Deferred nuclear refueling outage costs	26,072	7,080
Gas hedge contracts	52,789	- -
Prepayments and other	15,251	7,820
TOTAL	744,647	415,998
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	209,562	221,971
Non-utility property - at cost (less accumulated depreciation)	1,397	1,488
Note receivable - Entergy New Orleans	9,353	9,353
Other	504	4
TOTAL	220,816	232,816
UTILITY PLANT
Electric	6,671,733	6,550,597
Property under capital lease	253,387	253,387
Construction work in progress	321,695	276,974
Nuclear fuel under capital lease	98,511	44,532
TOTAL UTILITY PLANT	7,345,326	7,125,490
Less - accumulated depreciation and amortization	3,168,205	3,095,473
UTILITY PLANT - NET	4,177,121	4,030,017
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
SFAS 109 regulatory asset - net	116,388	117,322
Other regulatory assets	820,116	832,449
Deferred fuel costs	67,998	67,998
Long-term receivables	1,772	2,982
Other	25,948	23,539
TOTAL	1,032,222	1,044,290
TOTAL ASSETS	$6,174,806	$5,723,121
See Notes to Financial Statements.

90

ENTERGY LOUISIANA, LLC
BALANCE SHEETS
LIABILITIES AND MEMBERS' EQUITY
June 30, 2008 and December 31, 2007
(Unaudited)
	2008	2007
	(In Thousands)
CURRENT LIABILITIES
Accounts payable:
Associated companies	$174,405	$65,930
Other	224,518	148,651
Customer deposits	78,505	79,013
Taxes accrued	26,886	7,756
Accumulated deferred income taxes	73,567	- -
Interest accrued	22,491	29,739
Deferred fuel costs	- -	48,784
Obligations under capital leases	42,714	42,714
Pension and other postretirement liabilities	8,936	8,772
System agreement cost equalization	30,090	46,000
Other	11,020	18,961
TOTAL	693,132	496,320
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	1,763,322	1,803,430
Accumulated deferred investment tax credits	84,446	86,045
Obligations under capital leases	55,797	1,818
Other regulatory liabilities	156,220	127,836
Decommissioning	266,841	257,066
Accumulated provisions	21,035	18,405
Pension and other postretirement liabilities	149,475	145,786
Long-term debt	1,287,666	1,147,660
Other	89,703	85,214
TOTAL	3,874,505	3,673,260
Commitments and Contingencies
MEMBERS' EQUITY
Preferred membership interests without sinking fund	100,000	100,000
Members' equity	1,534,173	1,481,509
Accumulated other comprehensive loss	(27,004)	(27,968)
TOTAL	1,607,169	1,553,541
TOTAL LIABILITIES AND MEMBERS' EQUITY	$6,174,806	$5,723,121
See Notes to Financial Statements.

91

ENTERGY LOUISIANA, LLC
STATEMENTS OF MEMBERS' EQUITY AND COMPREHENSIVE INCOME
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended
	2008		2007
	(In Thousands)
MEMBERS' EQUITY
Members' Equity - Beginning of period	$1,499,367		$1,367,152
Add:
Net income	36,544	$36,544	30,798	$30,798
Deduct:
Distributions declared:
Preferred membership interests	1,738	1,738	1,737	1,737
	1,738		1,737
Members' Equity - End of period	$1,534,173		$1,396,213
ACCUMULATED OTHER COMPREHENSIVE
INCOME (Net of Taxes):
Balance at beginning of period:
Pension and other postretirement liabilities	($27,486)		($25,184)
Pension and other postretirement liabilities (net of tax expense of $409 and $466)	482	482	511	511
Balance at end of period:
Pension and other postretirement liabilities	($27,004)		($24,673)
Comprehensive Income		$35,288		$29,572
	Six Months Ended
	2008		2007
	(In Thousands)
MEMBERS' EQUITY
Members' Equity - Beginning of period	$1,481,509		$1,344,003
Add:
Net income	56,139	$56,139	54,566	$54,566
Additional equity from parent	-		1,119
	56,139		55,685
Deduct:
Distributions declared:
Preferred membership interests	3,475	3,475	3,475	3,475
	3,475		3,475
Members' Equity - End of period	$1,534,173		$1,396,213
ACCUMULATED OTHER COMPREHENSIVE
INCOME (Net of Taxes):
Balance at beginning of period:
Pension and other postretirement liabilities	($27,968)		($25,695)
Pension and other postretirement liabilities (net of tax expense of $818 and $932)	964	964	1,022	1,022
Balance at end of period:
Pension and other postretirement liabilities	($27,004)		($24,673)
Comprehensive Income		$53,628		$52,113
See Notes to Financial Statements.

92

ENTERGY LOUISIANA, LLC
SELECTED OPERATING RESULTS
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended		Increase/
Description	2008	2007	(Decrease)	%
	(Dollars In Millions)
Electric Operating Revenues:
Residential	$215	$185	$30	16
Commercial	155	137	18	13
Industrial	259	217	42	19
Governmental	11	11	-	-
Total retail	640	550	90	16
Sales for resale
Associated companies	66	70	(4)	(6)
Non-associated companies	3	2	1	50
Other	45	34	11	32
Total	$754	$656	$98	15
Billed Electric Energy
Sales (GWh):
Residential	1,976	1,854	122	7
Commercial	1,435	1,375	60	4
Industrial	3,437	3,268	169	5
Governmental	113	109	4	4
Total retail	6,961	6,606	355	5
Sales for resale
Associated companies	630	610	20	3
Non-associated companies	30	26	4	15
Total	7,621	7,242	379	5
	Six Months Ended		Increase/
Description	2008	2007	(Decrease)	%
	(Dollars In Millions)
Electric Operating Revenues:
Residential	$397	$381	$16	4
Commercial	283	273	10	4
Industrial	464	442	22	5
Governmental	22	22	-	-
Total retail	1,166	1,118	48	4
Sales for resale
Associated companies	97	107	(10)	(9)
Non-associated companies	5	4	1	25
Other	51	45	6	13
Total	$1,319	$1,274	$45	4
Billed Electric Energy
Sales (GWh):
Residential	3,946	3,807	139	4
Commercial	2,743	2,674	69	3
Industrial	6,667	6,496	171	3
Governmental	230	224	6	3
Total retail	13,586	13,201	385	3
Sales for resale
Associated companies	1,110	952	158	17
Non-associated companies	53	58	(5)	(9)
Total	14,749	14,211	538	4

93

ENTERGY MISSISSIPPI, INC.

MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Second Quarter 2008 Compared to Second Quarter 2007

Net income increased slightly by $0.8 million primarily due to higher net revenue substantially offset by higher other operation and maintenance expenses and a higher effective income tax rate in 2008.

Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Net income increased slightly by $1.1 million primarily due to higher net revenue substantially offset by higher other operation and maintenance expenses, lower other income, and a higher effective income tax rate in 2008.

Net Revenue

Second Quarter 2008 Compared to Second Quarter 2007

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges. Following is an analysis of the change in net revenue comparing the second quarter 2008 to the second quarter 2007.

	Amount
	(In Millions)
2007 net revenue	$126.0
Base revenue	2.7
Attala costs	2.2
Price applied to unbilled electric sales	1.9
Volume/weather	1.9
Rider revenue	1.8
Other	(1.1)
2008 net revenue	$135.4

The base revenue variance is primarily due to a formula rate plan increase effective July 2007. The formula rate plan is discussed in Note 2 to the financial statements in the Form 10-K.

The Attala costs variance is primarily due to an increase in the Attala power plant costs that are recovered through the power management rider. 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. The recovery of Attala power plant costs is discussed in "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources - Use of Capital" in the Form 10-K.

The price applied to unbilled electric sales variance is primarily due to higher base rates included in the unbilled calculation. See Note 1 to the financial statements in the Form 10-K for further discussion of the accounting for unbilled revenues.

94

The volume/weather variance is primarily due to increased electricity usage in the residential and commercial sectors, including the effect of more favorable weather on billed electric sales compared to the same period in 2007. Billed retail electricity usage increased a total of 34 GWh in the residential and commercial sectors.

The rider revenue variance is the result of a storm damage rider that became effective in October 2007. The establishment of this rider results in an increase in rider revenue and a corresponding increase in other operation and maintenance expense for the storm reserve with no impact on net income.

Fuel and purchased power expenses and other regulatory charges

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

Other regulatory charges increased primarily due to increased recovery through the Grand Gulf Rider of Grand Gulf capacity costs due to higher rates and increased usage and increased recovery of costs associated with the power management recovery rider. There is no material effect on net income due to quarterly adjustments to the power management recovery rider.

Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges. Following is an analysis of the change in net revenue comparing the six months ended June 30, 2008 to the six months ended June 30, 2007.

	Amount
	(In Millions)
2007 net revenue	$220.0
Attala costs	5.6
Base revenue	5.4
Volume/weather	4.1
Rider revenue	3.7
Price applied to unbilled electric sales	2.0
Other	0.1
2008 net revenue	$240.9

The Attala costs variance is primarily due to an increase in the Attala power plant costs that are recovered through the power management rider. 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. The recovery of Attala power plant costs is discussed in "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources - Use of Capital" in the Form 10-K.

The base revenue variance is primarily due to a formula rate plan increase effective July 2007. The formula rate plan is discussed in Note 2 to the financial statements in the Form 10-K.

The volume/weather variance is primarily due to increased electricity usage in the residential and commercial sectors, including the effect of more favorable weather on billed electric sales compared to the same period in 2007. Billed retail electricity usage increased a total of 99 GWh in the residential and commercial sectors.

The rider revenue variance is the result of a storm damage rider that became effective in October 2007. The establishment of this rider results in an increase in rider revenue and a corresponding increase in other operation and maintenance expense for the storm reserve with no impact on net income.

95

The price applied to unbilled electric sales variance is primarily due to higher base rates included in the unbilled calculation. See Note 1 to the financial statements in the Form 10-K for further discussion of the accounting for unbilled revenues.

Gross operating revenues and other regulatory charges

Gross operating revenues increased primarily due to:

an increase of $16.6 million in fuel cost recoveries due to higher fuel rates and increased usage; and

the base revenue, volume/weather, and pass-through rider revenue variances discussed above.

Other regulatory charges increased primarily due to increased recovery through the Grand Gulf Rider of Grand Gulf capacity costs due to higher rates and increased usage and increased recovery of costs associated with the power management recovery rider. There is no material effect on net income due to quarterly adjustments to the power management recovery rider.

Other Income Statement Variances

Second Quarter 2008 Compared to Second Quarter 2007

Other operation and maintenance expenses increased primarily due to:

an increase of $2.8 million in loss reserves for storm damages;

an increase of $1.4 million due to higher fossil plant maintenance costs; and

an increase of $1.3 million due to increased commercial property insurance premiums.

Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Other operation and maintenance expenses increased primarily due to:

an increase of $5.1 million in loss reserves for storm damages;

an increase of $3.7 million in fossil expenses due to higher plant maintenance costs and Attala equipment service agreement expenses; and

an increase of $1.3 million due to increased commercial property insurance premiums.

Other income decreased primarily due to the gain recorded in 2007 on the sale of non-utility property.

Income Taxes

The effective income tax rate was 37.2% for the second quarter 2008 and 36% for the six months ended June 30, 2008. The difference in the effective income tax rate for the second quarter of 2008 versus the federal statutory rate of 35% is primarily due to state income taxes.

The effective income tax rate was 29.1% for the second quarter 2007 and 30.6% for the six months ended June 30, 2007. The difference in the effective income tax rates for the second quarter 2007 and the six months ended June 30, 2007 versus the federal statutory rate of 35% is primarily due to the amortization of investment tax credits and excess deferred income taxes and a federal tax reserve adjustment, partially offset by state income taxes and book and tax differences related to utility plant items. The decrease for the six months ended June 30, 2007 is also due to book and tax differences related to the allowance for equity funds used during construction.

96

Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2008 and 2007 were as follows:

		2008	2007
		(In Thousands)
Cash and cash equivalents at beginning of period		$40,582	$73,417
Cash flow provided by (used in):
	Operating activities	12,372	64,936
	Investing activities	(77,357)	16,619
	Financing activities	37,519	(107,814)
Net decrease in cash and cash equivalents		(27,466)	(26,259)
Cash and cash equivalents at end of period		$13,116	$47,158

Operating Activities

Cash flow provided by operating activities decreased $52.6 million for the six months ended June 30, 2008 compared to the six months ended June 30, 2007 primarily due to the decreased recovery of deferred fuel costs and securitization proceeds of $48 million received in 2007, partially offset by the timing of payments to vendors. Fuel prices have been increasing, and due to the time lag before the fuel recovery rate increases in response, Entergy Mississippi has under-recovered fuel costs thus far in 2008.

Investing Activities

Entergy Mississippi's investing activities used $77.4 million in cash flow for the six months ended June 30, 2008 compared to providing $16.6 million for the six months ended June 30, 2007 primarily due to the receipt of proceeds in 2007 from funds held in trust in 2006 that were used for the redemption in January 2007, prior to maturity, of its $100 million, 4.35% Series First Mortgage Bonds and money pool activity, partially offset by the transfer in 2007 of $30 million to a storm damage reserve escrow account.

Increases in Entergy Mississippi's receivable from the money pool are a use of cash flow, and Entergy Mississippi's receivable from the money pool increased by $7.4 million for the six months ended June 30, 2008 compared to decreasing by $13.9 million for the six months ended June 30, 2007. The money pool is an inter-company borrowing arrangement designed to reduce Entergy's subsidiaries' need for external short-term borrowings.

Financing Activities

Entergy Mississippi's financing activities provided $37.5 million in cash flow for the six months ended June 30, 2008 compared to using $107.8 million in cash flow for the six months ended June 30, 2007 primarily due to the redemption, prior to maturity, of $100 million of 4.35% Series First Mortgage Bonds in January 2007 and borrowings of $50 million in 2008 on Entergy Mississippi's credit facility.

97

Capital Structure

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

	June 30, 2008	December 31, 2007
Net debt to net capital	50.6%	48.4%
Effect of subtracting cash from debt	0.5%	1.5%
Debt to capital	51.1%	49.9%

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

Uses and Sources of Capital

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

Entergy Mississippi's receivables from the money pool were as follows:

June 30, 2008	December 31, 2007	June 30, 2007	December 31, 2006
(In Thousands)
$28,398	$20,997	$19,057	$39,573

In May 2007, $6.6 million of Entergy Mississippi's receivable from the money pool was replaced by a note receivable from Entergy New Orleans. See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

As discussed in the Form 10-K, Entergy Mississippi has two separate credit facilities in the aggregate amount of $50 million and renewed both facilities through May 2009. Borrowings under the credit facilities may be secured by a security interest in Entergy Mississippi's accounts receivable. As of June 30, 2008, $50 million was outstanding on the credit facilities.

In April 2008, Entergy Mississippi repurchased its $30 million series of Independence County Pollution Control Revenue Bonds due July 2022. At the time of repurchase, the bonds were converted from an Auction Rate mode to a Daily Mode. In June 2008, Entergy Mississippi remarketed the series and converted the bonds to a Multi Annual Mode and fixed the rate to maturity at 4.90%. Entergy Mississippi used the proceeds from the remarketing to repay short-term borrowings that were drawn on its credit facilities to repurchase the bonds in April 2008.

Significant Factors and Known Trends

See "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends" in the Form 10-K for a discussion of state and local rate regulation, federal regulation, the Energy Policy Act of 2005, and utility restructuring. Following is an update to that discussion.

98

State and Local Rate Regulation

Fuel and purchased power cost recovery

In May 2008, Entergy Mississippi filed its quarterly fuel adjustment factor for the third quarter 2008, effective beginning with July 2008 bills. The third quarter 2008 factor is $0.038861/kWh, which is an increase from the $0.010878/kWh factor for the second quarter 2008. The increase is due to a significant increase in fuel prices, and Entergy Mississippi has gone from an over-recovery to an under-recovery position during 2008. In July 2008, the MPSC began a proceeding to investigate the fuel procurement practices and fuel adjustment schedules of the Mississippi utility companies, including Entergy Mississippi. A two-day public hearing was held in July 2008, and after a recess as the MPSC reviewed information, the hearing resumed on August 5, 2008 for additional testimony by an expert witness retained by the MPSC. The expert witness presented testimony regarding a review of the utilities' fuel adjustment clauses.  The MPSC stated that the goal of the proceeding is fact-finding so that the MPSC may decide whether to amend the current fuel cost recovery process.

Formula rate plan filing

In March 2008, Entergy Mississippi made its annual scheduled formula rate plan filing for the 2007 test year with the MPSC.  The filing showed that a $10.1 million increase in annual electric revenues is warranted. In June 2008, Entergy Mississippi reached a settlement with the Mississippi Public Utilities Staff that results in a $3.8 million rate increase. An MPSC decision on the settlement is pending.

Federal Regulation

See "System Agreement Proceedings" and "Independent Coordinator of Transmission" in the "Significant Factors and Known Trends" section of Entergy Corporation and Subsidiaries Management's Financial Discussion and Analysis for updates to the discussion in the Form 10-K.

Critical Accounting Estimates

See "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates" in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy Mississippi's accounting for unbilled revenue and qualified pension and other postretirement benefits.

New Accounting Pronouncements

See "New Accounting Pronouncements" section of Entergy Corporation and Subsidiaries Management's Financial Discussion and Analysis for a discussion of new accounting pronouncements.

99

ENTERGY MISSISSIPPI, INC.
INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended		Six Months Ended
	2008	2007	2008	2007
	(In Thousands)		(In Thousands)
OPERATING REVENUES
Electric	$351,982	$345,916	$646,832	$616,441
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale	70,428	101,101	149,192	172,075
Purchased power	120,269	109,286	216,368	205,121
Other operation and maintenance	59,240	52,593	110,346	97,708
Taxes other than income taxes	15,163	16,875	29,974	31,890
Depreciation and amortization	20,860	19,942	41,274	40,211
Other regulatory charges - net	25,915	9,489	40,400	19,284
TOTAL	311,875	309,286	587,554	566,289
OPERATING INCOME	40,107	36,630	59,278	50,152
OTHER INCOME
Allowance for equity funds used during construction	838	717	1,614	2,393
Interest and dividend income	564	1,193	774	2,641
Miscellaneous - net	1,606	(60)	944	2,192
TOTAL	3,008	1,850	3,332	7,226
INTEREST AND OTHER CHARGES
Interest on long-term debt	10,195	10,437	20,745	20,819
Other interest - net	1,309	1,247	2,445	2,482
Allowance for borrowed funds used during construction	(468)	(461)	(902)	(1,580)
TOTAL	11,036	11,223	22,288	21,721
INCOME BEFORE INCOME TAXES	32,079	27,257	40,322	35,657
Income taxes	11,949	7,926	14,513	10,917
NET INCOME	20,130	19,331	25,809	24,740
Preferred dividend requirements and other	707	707	1,414	1,414
EARNINGS APPLICABLE TO
COMMON STOCK	$19,423	$18,624	$24,395	$23,326
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, INC.
STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2008 and 2007
(Unaudited)
	2008	2007
	(In Thousands)
OPERATING ACTIVITIES
Net income	$25,809	$24,740
Adjustments to reconcile net income to net cash flow provided by operating activities:
Other regulatory charges - net	40,400	19,284
Depreciation and amortization	41,274	40,211
Deferred income taxes, investment tax credits, and non-current taxes accrued	(899)	(9,601)
Changes in working capital:
Receivables	(44,248)	(51,782)
Fuel inventory	817	(796)
Accounts payable	78,455	25,687
Taxes accrued	(4,678)	3,390
Interest accrued	1,026	1,166
Deferred fuel costs	(121,576)	(49,507)
Other working capital accounts	(27,681)	25,726
Provision for estimated losses and reserves	(7,320)	39,016
Changes in other regulatory assets	6,250	19,764
Other	24,743	(22,362)
Net cash flow provided by operating activities	12,372	64,936
INVESTING ACTIVITIES
Construction expenditures	(70,992)	(72,305)
Allowance for equity funds used during construction	1,614	2,393
Changes in other temporary investments - net	-	100,000
Change in money pool receivable - net	(7,401)	13,915
Proceeds from sale of assets	-	2,616
Payment to storm reserve escrow account	(578)	(30,000)
Net cash flow provided by (used in) investing activities	(77,357)	16,619
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	29,533	-
Retirement of long-term debt	(30,000)	(100,000)
Change in credit borrowings - net	50,000	-
Dividends paid:
Common stock	(10,600)	(6,400)
Preferred stock	(1,414)	(1,414)
Net cash flow provided by (used in) financing activities	37,519	(107,814)
Net decrease in cash and cash equivalents	(27,466)	(26,259)
Cash and cash equivalents at beginning of period	40,582	73,417
Cash and cash equivalents at end of period	$13,116	$47,158
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized	$21,120	$21,050
Income taxes	$4,209	$7,160
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, INC.
BALANCE SHEETS
ASSETS
June 30, 2008 and December 31, 2007
(Unaudited)
	2008	2007
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$1,010	$117
Temporary cash investments - at cost,
which approximates market	12,106	40,465
Total cash and cash equivalents	13,116	40,582
Accounts receivable:
Customer	71,092	62,052
Allowance for doubtful accounts	(763)	(615)
Associated companies	55,301	23,534
Other	7,410	8,234
Accrued unbilled revenues	45,349	33,535
Total accounts receivable	178,389	126,740
Deferred fuel costs	44,994	- -
Accumulated deferred income taxes	- -	7,686
Fuel inventory - at average cost	9,549	10,366
Materials and supplies - at average cost	30,067	30,167
Gas hedge contracts	44,760	- -
Prepayments and other	10,868	13,701
TOTAL	331,743	229,242
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	5,531	5,531
Non-utility property - at cost (less accumulated depreciation)	5,071	5,140
Storm reserve escrow account	31,326	30,748
Note receivable - Entergy New Orleans	7,610	7,610
TOTAL	49,538	49,029
UTILITY PLANT
Electric	2,886,354	2,829,065
Property under capital lease	8,470	9,116
Construction work in progress	76,697	72,753
TOTAL UTILITY PLANT	2,971,521	2,910,934
Less - accumulated depreciation and amortization	1,028,160	995,902
UTILITY PLANT - NET	1,943,361	1,915,032
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
SFAS 109 regulatory asset - net	38,330	29,868
Other regulatory assets	128,872	141,717
Other	22,459	21,381
TOTAL	189,661	192,966
TOTAL ASSETS	$2,514,303	$2,386,269
See Notes to Financial Statements.

102

ENTERGY MISSISSIPPI, INC.
BALANCE SHEETS
LIABILITIES AND SHAREHOLDERS' EQUITY
June 30, 2008 and December 31, 2007
(Unaudited)
	2008	2007
	(In Thousands)
CURRENT LIABILITIES
Notes payable	$50,000	$-
Accounts payable:
Associated companies	45,443	46,424
Other	115,540	36,104
Customer deposits	56,603	55,719
Taxes accrued	31,360	36,038
Accumulated deferred income taxes	5,846	- -
Interest accrued	16,220	15,194
Deferred fuel costs	- -	76,582
System agreement cost equalization	17,511	- -
Other	4,656	8,905
TOTAL	343,179	274,966
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	525,786	535,469
Accumulated deferred investment tax credits	9,177	9,748
Obligations under capital lease	7,122	7,806
Other regulatory liabilities	69,793	- -
Asset retirement cost liabilities	4,646	4,505
Accumulated provisions	42,944	50,264
Pension and other postretirement liabilities	54,050	56,946
Long-term debt	695,298	695,266
Other	41,457	44,243
TOTAL	1,450,273	1,404,247
Commitments and Contingencies
SHAREHOLDERS' EQUITY
Preferred stock without sinking fund	50,381	50,381
Common stock, no par value, authorized 15,000,000
shares; issued and outstanding 8,666,357 shares in 2008 and 2007	199,326	199,326
Capital stock expense and other	(690)	(690)
Retained earnings	471,834	458,039
TOTAL	720,851	707,056
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$2,514,303	$2,386,269
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, INC.
SELECTED OPERATING RESULTS
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended		Increase/
Description	2008	2007	(Decrease)	%
	(Dollars In Millions)
Electric Operating Revenues:
Residential	$ 116	$ 113	$ 3	3
Commercial	108	105	3	3
Industrial	44	48	(4)	(8)
Governmental	10	10	-	- -
Total retail	278	276	2	1
Sales for resale
Associated companies	36	36	-	- -
Non-associated companies	9	9	-	- -
Other	29	25	4	16
Total	$ 352	$ 346	$ 6	2
Billed Electric Energy
Sales (GWh):
Residential	1,157	1,141	16	1
Commercial	1,162	1,144	18	2
Industrial	621	695	(74)	(11)
Governmental	101	101	-	- -
Total retail	3,041	3,081	(40)	(1)
Sales for resale
Associated companies	217	303	(86)	(28)
Non-associated companies	113	119	(6)	(5)
Total	3,371	3,503	(132)	(4)
	Six Months Ended		Increase/
Description	2008	2007	(Decrease)	%
	(Dollars In Millions)
Electric Operating Revenues:
Residential	$ 227	$ 214	$ 13	6
Commercial	207	195	12	6
Industrial	86	89	(3)	(3)
Governmental	20	19	1	5
Total retail	540	517	23	4
Sales for resale
Associated companies	56	52	4	8
Non-associated companies	15	15	-	- -
Other	36	32	4	13
Total	$ 647	$ 616	31	5
Billed Electric Energy
Sales (GWh):
Residential	2,446	2,393	53	2
Commercial	2,259	2,213	46	2
Industrial	1,243	1,348	(105)	(8)
Governmental	196	195	1	1
Total retail	6,144	6,149	(5)	- -
Sales for resale
Associated companies	398	449	(51)	(11)
Non-associated companies	149	203	(54)	(27)
Total	6,691	6,801	(110)	(2)

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ENTERGY NEW ORLEANS, INC.

MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS

Hurricane Katrina

See the Form 10-K for a discussion of the effects of Hurricane Katrina, which in August 2005 caused catastrophic damage to Entergy New Orleans' service territory, including the effect of extensive flooding that resulted from levee breaks in and around the New Orleans area, and Entergy's initiatives to recover storm restoration and business continuity costs.

Bankruptcy Proceedings

See the Form 10-K for a discussion of the significant terms in Entergy New Orleans' plan of reorganization that became effective in May 2007.

Insurance Claim

In April 2008, Entergy received from its primary insurer $53.6 million of additional insurance proceeds on its Hurricane Katrina claim, and almost all of the April 2008 proceeds were allocated to Entergy New Orleans.

Entergy has settled its lawsuit against one of its excess insurers on the Hurricane Katrina claim, and in July 2008 received $71.5 million in proceeds on the claim. The July 2008 proceeds were allocated as follows: $2.0 million to Entergy Arkansas, $3.7 million to Entergy Gulf States Louisiana, $12.4 million to Entergy Louisiana, $1.8 million to Entergy Mississippi, and $48.4 million to Entergy New Orleans, with the remainder allocated in smaller amounts to other Entergy subsidiaries.

Results of Operations

Net Income

Second Quarter 2008 Compared to Second Quarter 2007

Net income remained relatively unchanged, decreasing $0.4 million.

Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Net income increased $4.4 million primarily due to higher net revenue partially offset by higher other operation and maintenance expenses and lower other income.

Net Revenue

Second Quarter 2008 Compared to Second Quarter 2007

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges. Following is an analysis of the changes in net revenue comparing the second quarter 2008 to the second quarter 2007.

105

	Amount
	(In Millions)
2007 net revenue	$62.1
Volume/weather	7.7
Price applied to unbilled electric sales	(3.6)
Other	0.4
2008 net revenue	$66.6

The volume/weather variance is due to an increase in electricity usage, including the effect of more favorable weather in 2008 compared to the same period in 2007. Billed retail electricity usage increased a total of 119 GWh, an increase of 12%.

The price applied to unbilled electric sales variance is primarily due to the fuel cost component of the price applied to unbilled sales included in the unbilled revenue calculation. See Note 1 to the financial statements in the Form 10-K for further discussion of the accounting for unbilled revenues.

Gross operating revenues and fuel and purchased power expenses

Gross operating revenues increased primarily due to:

an increase of $42.1 million in gross wholesale revenue due to increased sales to affiliated customers;

an increase of $11.7 million in fuel cost recovery revenues due to higher fuel rates and increased usage; and

an increase of $7.7 million related to volume/weather, as discussed above.

Fuel and purchased power increased primarily due to an increase in the average market price of natural gas and an increase in demand.

Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses, and 3) other regulatory charges. Following is an analysis of the changes in net revenue comparing the six months ended June 30, 2008 to the six months ended June 30, 2007.

	Amount
	(In Millions)
2007 net revenue	$112.1
Volume/weather	11.2
Net gas revenue	4.6
Other	1.1
2008 net revenue	$129.0

The volume/weather variance is due to an increase in electricity usage, including the effect of more favorable weather in 2008 compared to the same period in 2007. Billed retail electricity usage increased a total of 211 GWh, an increase of 11%.

The net gas revenue variance is primarily due to an increase in base rates and increased usage. Refer to Note 2 to the financial statements in the Form 10-K for a discussion of the base rate increase.

106

Gross operating revenues and fuel and purchased power expenses

Gross operating revenues increased primarily due to:

an increase of $45.0 million in gross wholesale revenue due to increased sales to affiliated customers and an increase in the average price of energy available for resale sales;

an increase of $19.8 million in fuel cost recovery revenues due to higher fuel rates and increased usage; and

the volume/weather variance of $11.2 million as discussed above.

Fuel and purchased power increased primarily due to increases in the average market prices of natural gas and purchased power in addition to an increase in demand.

Other Income Statement Variances

Second Quarter 2008 Compared to Second Quarter 2007

Other operation and maintenance expenses increased primarily due to:

a net reorganization credit in 2007 of $3.2 million related to the Entergy New Orleans bankruptcy; and

an increase of $0.8 million in distribution spending primarily due to increased labor costs and vegetation maintenance expense.

Other income decreased primarily due to a reduction in the allowance for equity funds used during construction related to a decrease in storm-related construction and lower carrying costs related to the Hurricane Katrina storm costs regulatory asset.

Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Other operation and maintenance expenses increased primarily due to:

an increase of $1.8 million due to the accrual of an Energy Efficiency Fund in the first quarter 2008;

an increase of $1.6 million in fossil expenses primarily due to higher costs for plant maintenance outages as a result of differing outage schedules for 2008 compared to 2007;

an increase of $1.2 million in distribution spending due to increased labor costs and vegetation maintenance expense; and

an increase of $0.9 million in transmission spending primarily due to higher transmission equalization expenses.

Other income decreased primarily due to a reduction in the allowance for equity funds used during construction related to a decrease in storm-related construction and a reduction in the carrying costs related to the Hurricane Katrina storm costs regulatory asset.

Income Taxes

The effective income tax rate was 35.1% for the second quarter 2008 and 41.4% for the six months ended June 30, 2008. The effective tax rate for the second quarter 2008 was reduced by a $1.1 million adjustment to income tax expense that related to expense for the first quarter 2008. The effective income tax rate for the six months ended June 30, 2008 was higher than the federal statutory rate of 35% primarily due to state income taxes and book and tax differences related to utility plant items.

The effective income tax rate was 42.0% for the second quarter 2007 and 40.3% for the six months ended June 30, 2007. The effective income tax rate for the second quarter 2007 was higher than the federal statutory rate of 35% primarily due to state income taxes and book and tax differences related to utility plant items. The effective income tax rate for the six months ended June 30, 2007 was higher than the federal statutory rate of 35%

107

primarily due to state income taxes and book and tax differences related to utility plant items, partially offset by the amortization of deferred income taxes and book and tax differences related to the allowance for equity funds used during construction.

Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2008 and 2007 were as follows:

		2008	2007
		(In Thousands)
Cash and cash equivalents at beginning of period		$92,010	$17,093
Cash flow provided by (used in):
	Operating activities	42,262	131,477
	Investing activities	(80,221)	30,804
	Financing activities	(482)	(53,345)
Net increase (decrease) in cash and cash equivalents		(38,441)	108,936
Cash and cash equivalents at end of period		$53,569	$126,029

Operating Activities

Net cash provided by operating activities decreased $89.2 million for the six months ended June 30, 2008 compared to the six months ended June 30, 2007 primarily due to the receipt of CDBG funds of $176.8 million in 2007 and the timing of collections of receivables from customers, partially offset by the timing of payments to vendors and an increase of $28.5 million in pension contributions.

Investing Activities

Investing activities used $80.2 million of cash for the six months ended June 30, 2008 compared to providing $30.8 million of cash for the six months ended June 30, 2007 primarily due to money pool activity, additional work performed on the gas distribution rebuild project, and proceeds of $10 million received in 2007 related to the sale in the first quarter 2007 of a power plant that had been out of service since 1984. Increases in Entergy New Orleans' receivable from the money pool are a use of cash flow, and Entergy New Orleans' receivable from the money pool increased by $77.1 million for the six months ended June 30, 2008. The money pool is an inter-company borrowing arrangement designed to reduce Entergy's subsidiaries' need for external short-term borrowings.

Financing Activities

Net cash used in financing activities decreased $52.9 million for the six months ended June 30, 2008 compared to the six months ended June 30, 2007 primarily due to a repayment of Entergy New Orleans' borrowings under the debtor in possession credit facility in 2007.

Capital Structure

Entergy New Orleans' capitalization is shown in the following table. The increase in the net debt to net capital ratio is primarily due to the decrease in cash and cash equivalents as a result of an increase in Entergy New Orleans' money pool receivable.

108

	June 30, 2008	December 31, 2007
Net debt to net capital	53.6%	51.8%
Effect of subtracting cash from debt	4.8%	8.8%
Debt to capital	58.4%	60.6%

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

Uses and Sources of Capital

See "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources" in the Form 10-K for a discussion of Entergy New Orleans' uses and sources of capital. The following are updates to the Form 10-K.

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

June 30, 2008	December 31, 2007	June 30, 2007	December 31, 2006
(In Thousands)
$124,796	$47,705	$-	($37,166)

See Note 4 to the financial statements in the Form 10-K for a description of the money pool. As discussed in the Form 10-K, in May 2007, Entergy New Orleans issued notes in satisfaction of its affiliate prepetition accounts payable, including its indebtedness to the Entergy System money pool.

On August 1, 2008, Entergy New Orleans paid, at maturity, its $30 million of 3.875% Series first mortgage bonds.

Significant Factors and Known Trends

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

State and Local Rate Regulation

Retail Rates

In January 2008, Entergy New Orleans voluntarily implemented a 6.15% base rate credit (the recovery credit) for electric customers, which Entergy New Orleans estimates will return approximately $10.6 million to electric customers in 2008. Entergy New Orleans was able to implement this credit because during 2007 the recovery of New Orleans after Hurricane Katrina was occurring faster than expected in 2006 projections. In addition, Entergy New Orleans committed to set aside $2.5 million for an energy efficiency program focused on community education and outreach and weatherization of homes.

On July 31, 2008, Entergy New Orleans filed an electric and gas base rate case with the City Council. The filing requests an 11.75% return on common equity. The filing calls for a $23.0 million decrease in electric base rates, which includes keeping the recovery credit in effect, as well as

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realigning approximately $12.3 million of capacity costs from recovery through the fuel adjustment clause to electric base rates. The filing also calls for a $9.1 million increase in gas base rates to fund on-going operations. This request is unrelated to the on-going rebuild of Entergy New Orleans' natural gas system. The procedural schedule calls for a hearing on the filing to commence on January 5, 2009, with certification of the evidentiary record by a hearing officer on or before February 28, 2009.

Fuel Adjustment Clause Litigation

See the Form 10-K for a discussion of the complaint filed in April 1999 by a group of ratepayers against Entergy New Orleans, Entergy Corporation, Entergy Services, and Entergy Power in state court in Orleans Parish purportedly on behalf of all Entergy New Orleans ratepayers and a corresponding complaint filed with the City Council. In February 2004, the City Council approved a resolution that resulted in a refund to customers of $11.3 million, including interest, during the months of June through September 2004. In May 2005 the Civil District Court for the Parish of Orleans affirmed the City Council resolution, finding no support for the plaintiffs' claim that the refund amount should be higher. In June 2005, the plaintiffs appealed the Civil District Court decision to the Louisiana Fourth Circuit Court of Appeal. On February 25, 2008, the Fourth Circuit Court of Appeal issued a decision affirming in part, and reversing in part, the Civil District Court's decision.  Although the Fourth Circuit Court of Appeal did not reverse any of the substantive findings and conclusions of the City Council or the Civil District Court, the Fourth Circuit found that the amount of the refund was arbitrary and capricious and increased the amount of the refund to $34.3 million.  Entergy New Orleans believes that the increase in the refund ordered by the Fourth Circuit is not justified. Entergy New Orleans, the City Council, and the plaintiffs requested rehearing, and in April 2008, the Fourth Circuit granted the plaintiffs' request for rehearing. In addition to changing the basis for the court's decision in the manner requested by the plaintiffs, the court also granted the plaintiffs' request that it provide for interest on the refund amount. The court denied the motions for rehearing filed by the City Council and Entergy New Orleans. In May 2008, Entergy New Orleans and the City Council filed with the Louisiana Supreme Court applications for a writ of certiorari seeking, among other things, reversal of the Fourth Circuit decision.

Federal Regulation

See "System Agreement Proceedings" and "Independent Coordinator of Transmission" in the "Significant Factors and Known Trends" section of Entergy Corporation and Subsidiaries Management's Financial Discussion and Analysis for updates to the discussion in the Form 10-K.

Critical Accounting Estimates

See "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates" in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy New Orleans' accounting for unbilled revenue and qualified pension and other postretirement benefits.

New Accounting Pronouncements

See "New Accounting Pronouncements" section of Entergy Corporation and Subsidiaries Management's Financial Discussion and Analysis for a discussion of new accounting pronouncements.

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ENTERGY NEW ORLEANS, INC.
INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended		Six Months Ended
	2008	2007	2008	2007
	(In Thousands)		(In Thousands)
OPERATING REVENUES
Electric	$194,567	$137,668	$334,795	$259,287
Natural gas	32,941	25,820	84,067	72,843
TOTAL	227,508	163,488	418,862	332,130
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale	101,058	54,162	180,957	131,593
Purchased power	58,795	46,196	106,806	86,355
Other operation and maintenance	27,413	22,247	52,233	46,795
Taxes other than income taxes	10,099	9,028	20,233	18,802
Depreciation and amortization	8,209	7,987	16,303	16,110
Other regulatory charges - net	1,029	1,032	2,059	2,065
TOTAL	206,603	140,652	378,591	301,720
OPERATING INCOME	20,905	22,836	40,271	30,410
OTHER INCOME
Allowance for equity funds used during construction	57	268	135	1,459
Interest and dividend income	2,492	3,292	4,846	6,025
Miscellaneous - net	(255)	(188)	(1,016)	(367)
TOTAL	2,294	3,372	3,965	7,117
INTEREST AND OTHER CHARGES
Interest on long-term debt	3,239	3,245	6,480	6,490
Other interest - net	2,076	2,426	4,408	6,735
Allowance for borrowed funds used during construction	(37)	(199)	(87)	(1,097)
TOTAL	5,278	5,472	10,801	12,128
INCOME BEFORE INCOME TAXES	17,921	20,736	33,435	25,399
Income taxes	6,290	8,718	13,857	10,231
NET INCOME	11,631	12,018	19,578	15,168
Preferred dividend requirements and other	241	241	482	482
EARNINGS APPLICABLE TO
COMMON STOCK	$11,390	$11,777	$19,096	$14,686
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, INC.
STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2008 and 2007
(Unaudited)
	2008	2007
	(In Thousands)
OPERATING ACTIVITIES
Net income	$19,578	$15,168
Adjustments to reconcile net income to net cash flow provided by operating activities:
Other regulatory charges - net	2,059	2,065
Depreciation and amortization	16,303	16,110
Deferred income taxes, investment tax credits, and non-current taxes accrued	16,878	4,240
Changes in working capital:
Receivables	(17,115)	5,310
Fuel inventory	1,206	856
Accounts payable	18,311	(27,401)
Taxes accrued	(2,285)	3,856
Interest accrued	(334)	(13,205)
Deferred fuel costs	(16,153)	(9,864)
Other working capital accounts	(6,929)	(7,017)
Provision for estimated losses and reserves	3,330	2,455
Changes in other regulatory assets	11,516	179,753
Other	(4,103)	(40,849)
Net cash flow provided by operating activities	42,262	131,477
INVESTING ACTIVITIES
Construction expenditures	(50,770)	(34,837)
Allowance for equity funds used during construction	135	1,459
Insurance proceeds	50,953	55,406
Proceeds from the sale of assets	- -	10,046
Change in money pool receivable - net	(77,092)	- -
Change in other investments - net	(3,447)	(1,270)
Net cash flow provided by (used in) investing activities	(80,221)	30,804
FINANCING ACTIVITIES
Repayment of DIP credit facility	- -	(51,934)
Dividends paid:
Preferred stock	(482)	(1,411)
Net cash flow used in financing activities	(482)	(53,345)
Net increase (decrease) in cash and cash equivalents	(38,441)	108,936
Cash and cash equivalents at beginning of period	92,010	17,093
Cash and cash equivalents at end of period	$53,569	$126,029
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized	$10,848	$10,684
Income taxes	$1,270	$92
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, INC.
BALANCE SHEETS
ASSETS
June 30, 2008 and December 31, 2007
(Unaudited)
	2008	2007
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents
Cash	$370	$119
Temporary cash investments - at cost
which approximates market	53,199	91,891
Total cash and cash equivalents	53,569	92,010
Accounts receivable:
Customer	56,623	45,478
Allowance for doubtful accounts	(718)	(4,639)
Associated companies	139,649	58,952
Other	2,623	9,928
Accrued unbilled revenues	30,591	24,842
Total accounts receivable	228,768	134,561
Deferred fuel costs	33,434	17,281
Fuel inventory - at average cost	3,294	4,500
Materials and supplies - at average cost	9,710	9,007
Prepayments and other	9,177	2,539
TOTAL	337,952	259,898
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	3,259	3,259
Non-utility property at cost (less accumulated depreciation)	1,016	1,016
Other property and investments	8,719	5,272
TOTAL	12,994	9,547
UTILITY PLANT
Electric	758,453	745,426
Natural gas	194,746	201,870
Construction work in progress	7,804	14,144
TOTAL UTILITY PLANT	961,003	961,440
Less - accumulated depreciation and amortization	514,633	507,537
UTILITY PLANT - NET	446,370	453,903
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets	144,546	143,726
Long term receivables	- -	126
Other	9,087	8,995
TOTAL	153,633	152,847
TOTAL ASSETS	$950,949	$876,195
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, INC.
BALANCE SHEETS
LIABILITIES AND SHAREHOLDERS' EQUITY
June 30, 2008 and December 31, 2007
(Unaudited)
	2008	2007
	(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt	$30,000	$30,000
Accounts payable:
Associated companies	25,561	27,138
Other	43,254	23,366
Customer deposits	18,767	17,803
Taxes accrued	2,696	4,981
Accumulated deferred income taxes	9,301	1,754
Interest accrued	4,883	5,217
Other	9,392	9,944
TOTAL CURRENT LIABILITIES	143,854	120,203
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	122,332	114,729
Accumulated deferred investment tax credits	2,637	2,809
SFAS 109 regulatory liability - net	73,500	73,613
Other regulatory liabilities	9,856	9,522
Retirement cost liability	2,867	2,772
Accumulated provisions	17,659	14,329
Pension and other postretirement liabilities	11,886	15,484
Long-term debt	273,379	273,912
Gas system rebuild insurance proceeds	61,697	36,958
Other	14,962	14,640
TOTAL NON-CURRENT LIABILITIES	590,775	558,768
Commitments and Contingencies
SHAREHOLDERS' EQUITY
Preferred stock without sinking fund	19,780	19,780
Common stock, $4 par value, authorized 10,000,000
shares; issued and outstanding 8,435,900 shares in 2008
and 2007	33,744	33,744
Paid-in capital	36,294	36,294
Retained earnings	126,502	107,406
TOTAL	216,320	197,224
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$950,949	$876,195
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, INC.
SELECTED OPERATING RESULTS
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended		Increase/
Description	2008	2007	(Decrease)	%
	(Dollars In Millions)
Electric Operating Revenues:
Residential	$38	$30	$8	27
Commercial	47	43	4	9
Industrial	12	11	1	9
Governmental	19	17	2	12
Total retail	116	101	15	15
Sales for resale
Associated companies	67	26	41	158
Non-associated companies	2	-	2	- -
Other	10	11	(1)	(9)
Total	$195	$138	$57	41
Billed Electric Energy
Sales (GWh):
Residential	322	257	65	25
Commercial	452	419	33	8
Industrial	139	134	5	4
Governmental	192	176	16	9
Total retail	1,105	986	119	12
Sales for resale
Associated companies	478	225	253	112
Non-associated companies	7	4	3	75
Total	1,590	1,215	375	31
	Six Months Ended		Increase/
Description	2008	2007	(Decrease)	%
	(Dollars In Millions)
Electric Operating Revenues:
Residential	$71	$55	$16	29
Commercial	87	81	6	7
Industrial	22	21	1	5
Governmental	35	32	3	9
Total retail	215	189	26	14
Sales for resale
Associated companies	103	59	44	75
Non-associated companies	2	-	2	- -
Other	15	11	4	36
Total	$335	$259	$76	29
Billed Electric Energy
Sales (GWh):
Residential	628	491	137	28
Commercial	860	815	45	6
Industrial	270	271	(1)	- -
Governmental	370	340	30	9
Total retail	2,128	1,917	211	11
Sales for resale
Associated companies	804	575	229	40
Non-associated companies	10	6	4	67
Total	2,942	2,498	444	18

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ENTERGY TEXAS, INC.

MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS

Jurisdictional Separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana and Entergy Texas

See the Entergy Texas Form 10 for a discussion of the jurisdictional separation of Entergy Gulf States, Inc. into two vertically integrated utility companies, one operating under the sole retail jurisdiction of the PUCT, Entergy Texas, and the other operating under the sole retail jurisdiction of the LPSC, Entergy Gulf States Louisiana.

Because the jurisdictional separation was a transaction involving entities under common control, Entergy Texas recognized the assets and liabilities allocated to it at their carrying amounts in the accounts of Entergy Gulf States, Inc. at the time of the jurisdictional separation. Entergy Texas' financial statements contained herein report results of operations for 2007 as though the jurisdictional separation had occurred at the beginning of 2007.

Results of Operations

Net Income

Second Quarter 2008 Compared to Second Quarter 2007

Net income increased by $21.6 million primarily due to higher net revenue and a lower effective income tax rate.

Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Net income increased by $32.7 million primarily due to higher net revenue and a lower effective income tax rate.

Net Revenue

Second Quarter 2008 Compared to Second Quarter 2007

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses and 3) other regulatory charges. Following is an analysis of the change in net revenue comparing the second quarter of 2008 to the second quarter of 2007.

	Amount
	(In Millions)
2007 net revenue	$90.6
Volume/weather	11.0
Securitization transition charge	4.7
Other	14.1
2008 net revenue	$120.4

The volume/weather variance is primarily due to increased electricity usage, including electricity sales during the unbilled sales period and more favorable weather compared to the same period in 2007. Billed retail electricity usage increased a total of 284 GWh in all sectors. See Note 1 to the financial statements in the Entergy Texas Form 10 for a discussion of the accounting for unbilled revenues.

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The securitization transition charge variance is primarily due to the issuance of securitization bonds. In June 2007, Entergy Gulf States Reconstruction Funding I, LLC (EGSRF I), a company wholly-owned and consolidated by Entergy Texas, issued securitization bonds and with the proceeds purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. See Note 5 to the financial statements in the Entergy Texas Form 10 for additional information regarding the securitization bonds.

The Other variance is primarily caused by various operational effects of the jurisdictional separation on revenues and fuel and purchased power expenses.

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

Gross operating revenues increased $114.4 million primarily due to:

an increase of $47.6 million in affiliated wholesale revenue primarily due to increases in the cost of energy;

an increase of $44.2 million in fuel cost recovery revenues due to higher fuel rates;

an increase of $11 million related to volume/weather as discussed above; and

an increase of $9.2 million in transition charge amounts collected from customers to service the securitization bonds. See Note 5 to the financial statements in the Entergy Texas Form 10 for additional information regarding the securitization bonds.

Fuel and purchased power expenses increased primarily due to an increase in gas generation and power purchases as a result of the purchased power agreements between Entergy Gulf States Louisiana and Entergy Texas and an increase in the average market prices of natural gas and purchased power, substantially offset by a decrease in deferred fuel expense as the result of decreased recovery from customers of fuel costs.

Other regulatory charges increased primarily due to the recovery of $4.4 million of bond expenses related to the securitization bonds. The recovery became effective July 2007. See Note 5 to the financial statements in the Entergy Texas Form 10 for additional information regarding the securitization bonds.

Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Net revenue consists of operating revenues net of: 1) fuel, fuel-related expenses, and gas purchased for resale, 2) purchased power expenses and 3) other regulatory charges. Following is an analysis of the change in net revenue comparing the six months ended June 30, 2008 to the six months ended June 30, 2007.

	Amount
	(In Millions)
2007 net revenue	$166.2
Fuel recovery	12.9
Volume/weather	12.2
Securitization transition charge	9.6
Other	17.0
2008 net revenue	$217.9

The fuel recovery variance is primarily due to a reserve for potential rate refunds made in the first quarter 2007 as a result of a PUCT ruling related to the application of past PUCT rulings addressing transition to competition in Texas.

The volume/weather variance is primarily due to increased electricity usage which increased a total of 452 GWh in all sectors. See Note 1 to the financial statements in the Entergy Texas Form 10 for a discussion of the accounting for unbilled revenues.

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The securitization transition charge variance is primarily due to the issuance of securitization bonds. In June 2007, EGSRF I, a company wholly-owned and consolidated by Entergy Texas, issued securitization bonds and with the proceeds purchased from Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts sufficient to service the securitization bonds. See Note 5 to the financial statements in the Entergy Texas Form 10 for additional information regarding the securitization bonds.

The Other variance is primarily caused by various operational effects of the jurisdictional separation on revenues and fuel and purchased power expenses.

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

Gross operating revenues increased $92.1 million primarily due to the following reasons:

an increase of $68 million in affiliated wholesale revenue primarily due to increases in the cost of energy;

an increase of $17.9 million in transition charge amounts collected from customers to service the securitization bonds. See Note 5 to the financial statements in the Entergy Texas Form 10 for additional information regarding the securitization bonds;

an increase of $12.2 million related to volume/weather as discussed above; and

implementation of an interim surcharge to collect $10.3 million in under-recovered incremental purchased capacity costs incurred through July 2007. The surcharge was collected over a two-month period beginning February 2008. The incremental capacity recovery rider and PUCT approval is discussed in Note 2 to the financial statements in the Entergy Texas Form 10.

The increase was partially offset by a decrease of $19.3 million in fuel cost recovery revenues primarily due to interim fuel refunds to customers for fuel cost recovery over-collections through November 2007. The refund was distributed over a two-month period beginning February 2008. The interim refund and the PUCT approval is discussed in Note 2 to the financial statements in the Entergy Texas Form 10.

Fuel and purchased power expenses increased primarily due to an increase in gas generation and power purchases as a result of the purchased power agreements between Entergy Gulf States Louisiana and Entergy Texas and an increase in the average market prices of natural gas and purchased power, substantially offset by a decrease in deferred fuel expense as the result of decreased recovery from customers of fuel costs.

Other regulatory charges increased primarily due to the recovery of $8.3 million of bond expenses related to the securitization bonds. The recovery became effective July 2007. See Note 5 to the financial statements in the Entergy Texas Form 10 for additional information regarding the securitization bonds.

Other Income Statement Variances

Second Quarter 2008 Compared to Second Quarter 2007

The other income variance includes an increase in taxes collected on advances for transmission projects, substantially offset by the absence of carrying charges on storm restoration costs that were approved by the PUCT in the first quarter 2007. In June 2007, EGSRF I issued securitization bonds and the carrying charges ended. The PUCT approval of carrying charges, the securitization filing and the approval for the recovery of reconstruction costs are discussed in Note 2 to the financial statements in the Entergy Texas Form 10.

Six Months Ended June 30, 2008 Compared to Six Months Ended June 30, 2007

Other operation and maintenance expenses decreased primarily due to a decrease of $2.9 million in customer service support costs, including a decrease in customer write-offs and a decrease of $2.2 million in transmission spending due to lower transmission equalization expenses. The decrease was partially offset by an increase of $1.3 million in payroll-related costs.

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Other income decreased primarily due to the absence of carrying charges on storm restoration costs that were approved by the PUCT in the first quarter 2007. In June 2007, EGSRF I issued securitization bonds and the carrying charges ended. The PUCT approval of carrying charges, the securitization filing and the approval for the recovery of reconstruction costs are discussed in Note 2 to the financial statements in the Entergy Texas Form 10. The decrease was partially offset by an increase in taxes collected on advances for transmission projects.

Interest and other charges increased primarily due to the increase in long-term debt outstanding as a result of the issuance of securitization bonds during the second quarter 2007, substantially offset by interest recorded in the first quarter 2007 on advances from independent power producers per a FERC order. See Note 5 to the financial statements in the Entergy Texas Form 10 for additional information regarding the securitization bonds.

Income Taxes

The effective income tax rate was 37.5% for the second quarter 2008 and 37.3% for the six months ended June 30, 2008. The differences in the effective income tax rate for the second quarter 2008 and for the six months ended June 30, 2008 versus the federal statutory rate of 35% were primarily due to state income taxes, partially offset by an adjustment of the federal income tax reserve for prior tax years.

Income tax expense for the second quarter 2007 was primarily due to state income taxes and adjustments related to FIN 48. Income tax expense for the six months ended June 30, 2007 was primarily due to state income taxes and adjustments related to FIN 48, partially offset by the amortization of investment tax credits.

Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2008 and 2007 were as follows:

		2008	2007
		(In Thousands)
Cash and cash equivalents at beginning of period		$297,082	$77,115
Cash flow provided by (used in):
	Operating activities	(13,513)	212,227
	Investing activities	60,412	(266,854)
	Financing activities	(321,232)	302,304
Net increase (decrease) in cash and cash equivalents		(274,333)	247,677
Cash and cash equivalents at end of period		$22,749	$324,792

Operating Activities

Operating activities used cash of $13.5 million for the six months ended June 30, 2008 compared to providing cash of $212.2 million for the six months ended June 30, 2007 primarily due to decreased recovery of deferred fuel costs, substantially offset by the timing of payments to vendors and the collection of receivables from customers. The decreased fuel recovery was primarily caused by the $71 million fuel cost over-recovery refund that is discussed in Note 2 to the financial statements, in addition to the over-recovery of fuel costs for the six months ended June 30, 2007 compared to under-recovering for the six months ended June 30, 2008. Fuel prices have been increasing, and due to the time lag before the fuel recovery rate increases in response, Entergy Texas has under-recovered fuel costs thus far in 2008.

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Investing Activities

Investing activities provided cash of $60.4 million for the six months ended June 30, 2008 compared to using cash of $266.9 million for the six months ended June 30, 2007 primarily due to money pool activity. Decreases in Entergy Texas' receivable from the money pool are a source of cash flow, and Entergy Texas' receivable from the money pool decreased by $104.3 million for the six months ended June 30, 2008 compared to increasing by $203.2 million for the six months ended June 30, 2007. The money pool is an inter-company borrowing arrangement designed to reduce Entergy's subsidiaries' need for external short-term borrowings.

Financing Activities

Financing activities used cash of $321.2 million for the six months ended June 30, 2008 compared to providing cash of $302.3 million for the six months ended June 30, 2007 primarily due to the issuance of $329.5 million of securitization bonds in June 2007, the retirement of $159.2 million of long-term debt in June 2008, and $150 million of capital returned to Entergy Corporation in February 2008. After the effects of Hurricane Katrina and Hurricane Rita, Entergy Corporation made a $300 million capital contribution to Entergy Gulf States, Inc. in 2005, which was part of Entergy's financing plan that provided liquidity and capital resources to Entergy and its subsidiaries while storm restoration cost recovery was pursued. See Note 5 in the Entergy Texas Form 10 for additional information regarding the securitization bonds.

Capital Structure

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

	June 30, 2008	December 31, 2007
Net debt to net capital	58.5%	52.6%
Effect of subtracting cash from debt	0.5%	5.9%
Debt to capital	59.0%	58.5%

Net debt consists of debt less cash and cash equivalents. Debt consists of notes payable and long-term debt, including the currently maturing portion and also including the debt assumption liability. Capital consists of debt and shareholder's equity. Net capital consists of capital less cash and cash equivalents. Entergy Texas 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 Texas' financial condition.

On June 2, 2008, under the terms of the debt assumption agreement between Entergy Texas and Entergy Gulf States Louisiana that is discussed in Note 5 to the financial statements in the Entergy Texas Form 10, Entergy Texas paid at maturity $148.8 million of Entergy Gulf States Louisiana first mortgage bonds, which results in a corresponding decrease in Entergy Texas' debt assumption liability.

Uses and Sources of Capital

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

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Entergy Texas' receivables from the money pool were as follows:

June 30, 2008	December 31, 2007	June 30, 2007	December 31, 2006
(In Thousands)
$49,920	$154,176	300,458	$97,277

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

As discussed in the Entergy Texas Form 10, Entergy Texas has a credit facility in the amount of $100 million that will expire in August 2012. The facility became available to Entergy Texas on May 30, 2008, after the fulfillment of certain closing conditions, and no borrowings were outstanding under the facility as of June 30, 2008.

Significant Factors and Known Trends

See "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends" in the Entergy Texas Form 10 for a discussion of transition to retail competition in Texas; state and local rate regulation; federal regulation; the Energy Policy Act of 2005; industrial and commercial customers; market and credit risk sensitive instruments; and environmental risks. Following are updates to the information disclosed in the Entergy Texas Form 10.

State and Local Rate Regulation

Filings with the PUCT

Entergy Texas made a rate filing in September 2007 with the PUCT requesting an annual rate increase totaling $107.5 million, including a base rate increase of $64.3 million and riders totaling $43.2 million. The base rate increase includes a $12.2 million annual increase for the storm damage reserve. Entergy Texas requested an 11% return on common equity. In December 2007 the PUCT issued an order setting September 26, 2008 as the effective date for the rate change from the rate filing. In May 2008, Entergy Texas and certain parties in the rate case filed a non-unanimous settlement that provides for a $42.5 million base rate increase beginning in October 2008 and an additional $17 million base rate increase beginning in October 2009. The non-unanimous settlement also provides that $25 million of System Agreement rough production cost equalization payments will offset the effect on customers of the rate increase. The non-unanimous settlement further provides that an additional $17& nbsp;million on an annual basis of System Agreement rough production cost equalization payments will be retained by Entergy Texas from January 2009 through September 2009. The non-unanimous settlement also resolves the fuel reconciliation portion of the proceeding with a $4.5 million disallowance. The PUCT staff, the Texas Industrial Energy Consumers (TIEC), and the state of Texas did not join in the settlement and filed a separate agreement among them that provides for a rate decrease, later revised to a slight increase, and a $4.7 million fuel cost disallowance. In May 2008 the ALJs issued an order stating that the proceeding will continue with Entergy Texas having the burden of proof to show that the non-unanimous settlement results in reasonable rates. The hearing on the merits of the non-unanimous settlement was held from June 23 through July 2, 2008, and post-hearing briefing by the parties is ongoing.

In January 2008, Entergy Texas made a compliance filing with the PUCT describing how its 2007 Rough Production Cost Equalization receipts under the System Agreement were allocated between Entergy Gulf States, Inc.'s Texas and Louisiana jurisdictions. Several parties have intervened in the proceeding. A hearing was held at the end of July 2008, and a decision is pending.

In October 2007, Entergy Texas filed a request with the PUCT to refund $45.6 million, including interest, of fuel cost recovery over-collections through September 2007. In January 2008, Entergy Texas filed with the PUCT a stipulation and settlement agreement among the parties that updated the over-collection balance through November 2007 and establishes a refund amount, including interest, of $71 million. The PUCT approved the

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agreement in February 2008. The refund was made over a two-month period beginning February 2008, but was reduced by $10.3 million of under-recovered incremental purchased capacity costs. Amounts refunded through the interim fuel refund are subject to final reconciliation in a future fuel reconciliation proceeding.

Federal Regulation

See "System Agreement Proceedings" and "Independent Coordinator of Transmission" in the "Significant Factors and Known Trends" section of Entergy Corporation and Subsidiaries Management's Financial Discussion and Analysis herein for updates to the discussion in the Entergy Texas Form 10.

Critical Accounting Estimates

See "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates" in the Entergy Texas Form 10 for a discussion of the estimates and judgments necessary in Entergy Texas' accounting for the application of SFAS 71, unbilled revenue, and qualified pension and other postretirement benefits.

New Accounting Pronouncements

See "New Accounting Pronouncements" section of Entergy Corporation and Subsidiaries Management's Financial Discussion and Analysis for a discussion of new accounting pronouncements.

123

ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended		Six Months Ended
	2008	2007	2008	2007
	(In Thousands)		(In Thousands)
OPERATING REVENUES
Electric	$565,349	$450,905	$962,391	$870,293
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale	158,288	143,243	227,182	310,484
Purchased power	280,189	215,397	505,593	390,407
Other operation and maintenance	46,254	47,239	84,675	89,190
Decommissioning	46	42	91	84
Taxes other than income taxes	12,944	12,871	26,544	26,004
Depreciation and amortization	18,872	17,346	37,237	34,480
Other regulatory charges - net	6,518	1,620	11,697	3,183
TOTAL	523,111	437,758	893,019	853,832
OPERATING INCOME	42,238	13,147	69,372	16,461
OTHER INCOME
Allowance for equity funds used during construction	402	550	978	1,770
Interest and dividend income	1,346	9,983	5,553	19,789
Miscellaneous - net	9,276	(350)	11,086	(350)
TOTAL	11,024	10,183	17,617	21,209
INTEREST AND OTHER CHARGES
Interest on long-term debt	18,545	16,129	38,507	32,246
Other interest - net	698	2,426	2,575	7,114
Allowance for borrowed funds used during construction	(230)	(354)	(557)	(1,150)
TOTAL	19,013	18,201	40,525	38,210
INCOME (LOSS) BEFORE INCOME TAXES	34,249	5,129	46,464	(540)
Income taxes	12,833	5,291	17,336	3,018
NET INCOME (LOSS)	$21,416	($162)	$29,128	($3,558)
See Notes to Financial Statements.

124

ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2008 and 2007
(Unaudited)
	2008	2007
	(In Thousands)
OPERATING ACTIVITIES
Net income (loss)	$29,128	($3,558)
Adjustments to reconcile net income to net cash flow provided by operating activities:
Reserve for regulatory adjustments	188	179
Other regulatory charges - net	11,697	3,183
Depreciation, amortization, and decommissioning	37,328	34,564
Deferred income taxes, investment tax credits, and non-current taxes accrued	(1,695)	90,342
Changes in working capital:
Receivables	(22,625)	(93,959)
Fuel inventory	(2,385)	6,549
Accounts payable	168,607	4,727
Taxes accrued	10,907	17,669
Interest accrued	(5,735)	(37)
Deferred fuel costs	(130,734)	53,650
Other working capital accounts	(25,115)	58,923
Provision for estimated losses and reserves	1,208	481
Changes in other regulatory assets	17,342	(30,704)
Other	(101,629)	70,218
Net cash flow provided by (used in) operating activities	(13,513)	212,227
INVESTING ACTIVITIES
Construction expenditures	(53,993)	(69,858)
Allowance for equity funds used during construction	978	1,770
Insurance proceeds	-	4,415
Change in money pool receivable - net	104,256	(203,181)
Changes in transition charge account	9,171	-
Net cash flow provided by (used in) investing activities	60,412	(266,854)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	-	322,032
Return of capital to parent	(150,000)	-
Retirement of long-term debt	(159,232)	-
Dividends paid:
Common stock	(12,000)	(19,728)
Net cash flow provided by (used in) financing activities	(321,232)	302,304
Net increase (decrease) in cash and cash equivalents	(274,333)	247,677
Cash and cash equivalents at beginning of period	297,082	77,115
Cash and cash equivalents at end of period	$22,749	$324,792
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized	$44,855	$37,234
Income taxes	$6,493	$3,239
See Notes to Financial Statements.

125

ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
June 30, 2008 and December 31, 2007
(Unaudited)
	2008	2007
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$1,420	$10
Temporary cash investments - at cost,
which approximates market	21,329	297,072
Total cash and cash equivalents	22,749	297,082
Securitization recovery trust account	10,102	19,273
Accounts receivable:
Customer	90,000	61,108
Allowance for doubtful accounts	(738)	(918)
Associated companies	285,181	377,478
Other	10,728	35,048
Accrued unbilled revenues	36,888	30,974
Total accounts receivable	422,059	503,690
Deferred fuel costs	63,464	- -
Accumulated deferred income taxes	2,587	24,507
Fuel inventory - at average cost	58,163	55,778
Materials and supplies - at average cost	30,249	31,454
Prepayments and other	7,767	14,756
TOTAL	617,140	946,540
OTHER PROPERTY AND INVESTMENTS
Investments in affiliates at equity	876	863
Non-utility property - at cost (less accumulated depreciation)	1,883	2,030
Other	18,939	16,514
TOTAL	21,698	19,407
UTILITY PLANT
Electric	2,870,465	2,817,681
Construction work in progress	58,527	71,519
TOTAL UTILITY PLANT	2,928,992	2,889,200
Less - accumulated depreciation and amortization	1,064,370	1,043,183
UTILITY PLANT - NET	1,864,622	1,846,017
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
SFAS 109 regulatory asset - net	86,536	87,531
Other regulatory assets	628,167	645,941
Long-term receivables	789	1,284
Other	118,068	60,032
TOTAL	833,560	794,788
TOTAL ASSETS	$3,337,020	$3,606,752
See Notes to Financial Statements.
126
ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND SHAREHOLDER'S EQUITY
June 30, 2008 and December 31, 2007
(Unaudited)
	2008	2007
	(In Thousands)
CURRENT LIABILITIES
Currently maturing portion of debt assumption liability	$160,286	$309,123
Accounts payable:
Associated companies	107,381	40,120
Other	182,263	80,917
Customer deposits	39,478	37,962
Taxes accrued	26,660	15,753
Interest accrued	22,314	28,049
Deferred fuel costs	- -	67,270
Pension and other postretirement liabilities	1,236	1,236
System agreement cost equalization	56,126	92,225
Other	6,589	5,316
TOTAL	602,333	677,971
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	669,267	697,693
Accumulated deferred investment tax credits	24,926	25,724
Other regulatory liabilities	6,253	4,881
Asset retirement cost liabilities	3,156	3,066
Accumulated provisions	10,071	8,863
Pension and other postretirement liabilities	4,638	14,418
Long-term debt - assumption liability	769,971	769,971
Other long-term debt	322,851	333,892
Other	52,172	66,019
TOTAL	1,863,305	1,924,527
Commitments and Contingencies
SHAREHOLDER'S EQUITY
Common stock, no par value, authorized 200,000,000 shares;
issued and outstanding 46,525,000 shares in 2008 and 2007	49,452	49,452
Paid-in capital	481,994	631,994
Retained earnings	339,936	322,808
TOTAL	871,382	1,004,254
TOTAL LIABILITIES AND SHAREHOLDER'S EQUITY	$3,337,020	$3,606,752
See Notes to Financial Statements.

127

ENTERGY TEXAS, INC. AND SUBSIDIAIRES
CONSOLIDATED STATEMENTS OF RETAINED EARNINGS AND PAID-IN CAPITAL
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended
	2008	2007
	(In Thousands)
RETAINED EARNINGS
Retained Earnings - Beginning of period	$330,520	$287,918
Add:
Net Income (Loss)	21,416	(162)
Other additions	-	756
	21,416	594
Deduct:
Dividends declared on common stock	12,000	5,160
Retained Earnings - End of period	$339,936	$283,352
PAID-IN CAPITAL
Paid-in Capital - Beginning of period	$481,994	$632,222
Deduct:
Return of capital to parent	-	-
Paid-in capital - End of period	$481,994	$632,222
	Six Months Ended
	2008	2007
	(In Thousands)
RETAINED EARNINGS
Retained Earnings - Beginning of period	$322,808	$306,266
Add:
Net Income (Loss)	29,128	(3,558)
Other additions	-	372
	29,128	(3,186)
Deduct:
Dividends declared on common stock	12,000	19,728
Retained Earnings - End of period	$339,936	$283,352
PAID-IN CAPITAL
Paid-in Capital - Beginning of period	$631,994	$632,222
Deduct:
Return of capital to parent	(150,000)	-
Paid-in capital - End of period	$481,994	$632,222
See Notes to Financial Statements.

128

ENTERGY TEXAS, INC. AND SUBSIDIARIES
SELECTED OPERATING RESULTS
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended		Increase/
Description	2008	2007	(Decrease)	%
	(Dollars In Millions)
Electric Operating Revenues:
Residential	$149	$125	$24	19
Commercial	110	95	15	16
Industrial	135	113	22	19
Governmental	8	6	2	33
Total retail	402	339	63	19
Sales for resale
Associated companies	143	97	46	47
Non-associated companies	3	1	2	200
Other	17	14	3	21
Total	$565	$451	$114	25
Billed Electric Energy
Sales (GWh):
Residential	1,232	1,131	101	9
Commercial	1,042	985	57	6
Industrial	1,607	1,483	124	8
Governmental	62	60	2	3
Total retail	3,943	3,659	284	8
Sales for resale
Associated companies	1,079	1,083	(4)	- -
Non-associated companies	29	13	16	123
Total	5,051	4,755	296	6
	Six Months Ended		Increase/
Description	2008	2007	(Decrease)	%
	(Dollars In Millions)
Electric Operating Revenues:
Residential	$260	$258	$2	1
Commercial	187	186	1	1
Industrial	239	221	18	8
Governmental	13	12	1	8
Total retail	699	677	22	3
Sales for resale
Associated companies	239	172	67	39
Non-associated companies	5	3	2	67
Other	19	18	1	6
Total	$962	$870	$92	11
Billed Electric Energy
Sales (GWh):
Residential	2,444	2,367	77	3
Commercial	1,985	1,897	88	5
Industrial	3,151	2,867	284	10
Governmental	123	120	3	3
Total retail	7,703	7,251	452	6
Sales for resale
Associated companies	1,976	1,995	(19)	(1)
Non-associated companies	51	47	4	9
Total	9,730	9,293	437	5

129

SYSTEM ENERGY RESOURCES, INC.

MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

System Energy's principal asset consists of a 90% ownership and leasehold interest in Grand Gulf. The capacity and energy from its 90% interest is sold under the Unit Power Sales Agreement to its only four customers, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. System Energy's operating revenues are derived from the allocation of the capacity, energy, and related costs associated with its 90% interest in Grand Gulf pursuant to the Unit Power Sales Agreement. Payments under the Unit Power Sales Agreement are System Energy's only source of operating revenues.

Net income decreased by $4.9 million for the second quarter of 2008 compared to the second quarter of 2007 primarily due to a decrease in rate base in the second quarter of 2008 resulting in lower operating income. Lower interest income earned on money pool investments also contributed to the decrease in net income.

Net income decreased by $10.6 million for the six months ended June 30, 2008 compared to the six months ended June 30, 2007 primarily due to a decrease in rate base in 2008 resulting in lower operating income. Lower interest income earned on money pool investments also contributed to the decrease in net income.

Liquidity and Capital Resources

Cash Flow

Cash flows for the six months ended June 30, 2008 and 2007 were as follows:

		2008	2007
		(In Thousands)
Cash and cash equivalents at beginning of period		$105,005	$135,012
Cash flow provided by (used in):
	Operating activities	97,865	87,053
	Investing activities	(84,274)	(26,960)
	Financing activities	(71,901)	(74,235)
Net decrease in cash and cash equivalents		(58,310)	(14,142)
Cash and cash equivalents at end of period		$46,695	$120,870

Operating Activities

The increase of $10.8 million in net cash provided by operating activities for the six months ended June 30, 2008 compared to the six months ended June 30, 2007 is primarily due to a decrease of $9.6 million in income tax payments.

130

Investing Activities

The increase of $57.3 million in net cash used by investing activities for the six months ended June 30, 2008 compared to the six months ended June 30, 2007 is primarily due to money pool activity. Increases in System Energy's receivable from the money pool are a use of cash flow, and System Energy's receivable from the money pool increased by $47.9 million for the six months ended June 30, 2008 compared to decreasing by $14.8 million for the six months ended June 30, 2007. The money pool is an inter-company borrowing arrangement designed to reduce Entergy's subsidiaries' need for external short-term borrowings.

Capital Structure

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

	June 30, 2008	December 31, 2007
Net debt to net capital	47.9%	47.4%
Effect of subtracting cash from debt	1.4%	3.2%
Debt to capital	49.3%	50.6%

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

Uses and Sources of Capital

See "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources" in the Form 10-K for a discussion of System Energy's uses and sources of capital. The following is an update to the Form 10-K.

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

June 30, 2008	December 31, 2007	June 30, 2007	December 31, 2006
(In Thousands)
$101,497	$53,620	$50,865	$88,231

In May 2007, $22.5 million of System Energy's receivable from the money pool was replaced by a note receivable from Entergy New Orleans. See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Significant Factors and Known Trends

See "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Significant Factors and Known Trends" in the Form 10-K for a discussion of the Energy Policy Act of 2005, nuclear matters, and environmental risks. The following is an update to the Form 10-K.

System Energy Rate Proceeding

In March 2008, the LPSC filed a complaint at the FERC under Federal Power Act section 206 against System Energy and Entergy Services. The complaint requests that the FERC set System Energy's rate of return on common equity at no more than 9.75%. The LPSC's complaint further

131

requests that System Energy base its decommissioning and depreciation expenses on a 60-year useful life for Grand Gulf as opposed to the 40-year life specified in the existing NRC operating license. The APSC, the City of New Orleans, the MPSC, and other parties have intervened in the proceeding. System Energy filed its answer to the complaint in April 2008, in which it denies the allegations of the LPSC and requests that the FERC dismiss the complaint without a hearing. On July 1, 2008, the FERC issued an order denying the relief requested by the LPSC.

Critical Accounting Estimates

See "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates" in the Form 10-K for a discussion of the estimates and judgments necessary in System Energy's accounting for nuclear decommissioning costs and qualified pension and other postretirement benefits.

New Accounting Pronouncements

See "New Accounting Pronouncements" section of Entergy Corporation and Subsidiaries Management's Financial Discussion and Analysis for a discussion of new accounting pronouncements.

132

SYSTEM ENERGY RESOURCES, INC.
INCOME STATEMENTS
For the Three and Six Months Ended June 30, 2008 and 2007
(Unaudited)
	Three Months Ended		Six Months Ended
	2008	2007	2008	2007
	(In Thousands)		(In Thousands)
OPERATING REVENUES
Electric	$128,366	$129,471	$242,738	$255,628
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale	12,688	10,333	23,304	18,721
Nuclear refueling outage expenses	4,209	3,691	8,413	8,226
Other operation and maintenance	32,008	28,304	56,997	52,541
Decommissioning	6,847	6,369	13,571	12,624
Taxes other than income taxes	6,101	4,594	4,029	13,005
Depreciation and amortization	24,522	24,026	51,077	49,988
Other regulatory credits - net	(2,571)	(2,650)	(4,557)	(4,610)
TOTAL	83,804	74,667	152,834	150,495
OPERATING INCOME	44,562	54,804	89,904	105,133
OTHER INCOME
Allowance for equity funds used during construction	1,237	364	2,366	780
Interest and dividend income	3,665	4,770	6,212	10,585
Miscellaneous - net	(121)	657	(288)	578
TOTAL	4,781	5,791	8,290	11,943
INTEREST AND OTHER CHARGES
Interest on long-term debt	11,321	11,336	23,283	23,689
Other interest - net	37	36	80	52
Allowance for borrowed funds used during construction	(415)	(120)	(793)	(255)
TOTAL	10,943	11,252	22,570	23,486
INCOME BEFORE INCOME TAXES	38,400	49,343	75,624	93,590
Income taxes	16,309	22,379	31,932	39,329
NET INCOME	$22,091	$26,964	$43,692	$54,261
See Notes to Financial Statements.

133

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134

SYSTEM ENERGY RESOURCES, INC.
STATEMENTS OF CASH FLOWS
For the Six Months Ended June 30, 2008 and 2007
(Unaudited)
	2008	2007
	(In Thousands)
OPERATING ACTIVITIES
Net income	$43,692	$54,261
Adjustments to reconcile net income to net cash flow provided by operating activities:
Other regulatory credits - net	(4,557)	(4,610)
Depreciation, amortization, and decommissioning	64,648	62,612
Deferred income taxes, investment tax credits, and non-current taxes accrued	(3,659)	37,139
Changes in working capital:
Receivables	16,909	6,305
Accounts payable	(11,747)	(4,089)
Taxes accrued	- -	(43,461)
Interest accrued	(34,959)	(33,345)
Other working capital accounts	1,713	(21,355)
Provision for estimated losses and reserves	(488)	(22)
Changes in other regulatory assets	(5,679)	(1,400)
Other	31,992	35,018
Net cash flow provided by operating activities	97,865	87,053
INVESTING ACTIVITIES
Construction expenditures	(23,966)	(29,101)
Allowance for equity funds used during construction	2,366	780
Nuclear fuel purchases	- -	(56,155)
Proceeds from the sale/leaseback of nuclear fuel	- -	56,475
Proceeds from nuclear decommissioning trust fund sales	176,470	41,964
Investment in nuclear decommissioning trust funds	(191,266)	(55,761)
Changes in money pool receivable - net	(47,878)	14,838
Net cash flow used in investing activities	(84,274)	(26,960)
FINANCING ACTIVITIES
Retirement of long-term debt	(26,701)	(23,335)
Dividends paid:
Common stock	(45,200)	(50,900)
Net cash flow used in financing activities	(71,901)	(74,235)
Net decrease in cash and cash equivalents	(58,310)	(14,142)
Cash and cash equivalents at beginning of period	105,005	135,012
Cash and cash equivalents at end of period	$46,695	$120,870
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized	$55,753	$54,241
Income taxes	$16,072	$25,667
See Notes to Financial Statements.

135

SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
ASSETS
June 30, 2008 and December 31, 2007
(Unaudited)
	2008	2007
	(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash	$872	$406
Temporary cash investments - at cost,
which approximates market	45,823	104,599
Total cash and cash equivalents	46,695	105,005
Accounts receivable:
Associated companies	144,490	112,598
Other	2,998	3,921
Total accounts receivable	147,488	116,519
Materials and supplies - at average cost	74,250	68,613
Deferred nuclear refueling outage costs	5,687	13,640
Prepayments and other	9,828	9,225
TOTAL	283,948	313,002
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	304,672	315,654
Note receivable - Entergy New Orleans	25,560	25,560
TOTAL	330,232	341,214
UTILITY PLANT
Electric	3,285,637	3,273,390
Property under capital lease	475,157	475,157
Construction work in progress	99,110	88,296
Nuclear fuel under capital lease	64,385	81,616
Nuclear fuel	5,913	7,656
TOTAL UTILITY PLANT	3,930,202	3,926,115
Less - accumulated depreciation and amortization	2,156,637	2,101,484
UTILITY PLANT - NET	1,773,565	1,824,631
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
SFAS 109 regulatory asset - net	90,014	93,083
Other regulatory assets	281,394	274,202
Other	11,905	12,628
TOTAL	383,313	379,913
TOTAL ASSETS	$2,771,058	$2,858,760
See Notes to Financial Statements.

136

SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
LIABILITIES AND SHAREHOLDER'S EQUITY
June 30, 2008 and December 31, 2007
(Unaudited)
	2008	2007
	(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt	$28,440	$26,701
Accounts payable:
Associated companies	3,989	8,902
Other	22,348	29,182
Accumulated deferred income taxes	1,388	4,494
Interest accrued	12,444	47,403
Obligations under capital leases	30,058	30,058
TOTAL	98,667	146,740
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued	308,020	314,991
Accumulated deferred investment tax credits	63,446	65,184
Obligations under capital leases	34,326	51,558
Other regulatory liabilities	245,702	243,450
Decommissioning	382,131	368,559
Accumulated provisions	1,981	2,469
Pension and other postretirement liabilities	31,063	30,031
Long-term debt	744,863	773,266
Other	-	145
TOTAL	1,811,532	1,849,653
Commitments and Contingencies
SHAREHOLDER'S EQUITY
Common stock, no par value, authorized 1,000,000 shares;
issued and outstanding 789,350 shares in 2008 and 2007	789,350	789,350
Retained earnings	71,509	73,017
TOTAL	860,859	862,367
TOTAL LIABILITIES AND SHAREHOLDER'S EQUITY	$2,771,058	$2,858,760
See Notes to Financial Statements.

137

ENTERGY CORPORATION AND SUBSIDIARIES

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

See "PART I, Item 1, Litigation" in the Form 10-K for a discussion of legal, administrative, and other regulatory proceedings affecting Entergy.

Item 1A. Risk Factors

There have been no material changes to the risk factors discussed in "PART I, Item 1A, Risk Factors" in the Form 10-K.

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

Issuer Purchases of Equity Securities (1)

Period	Total Number of Shares Purchased	Average Price Paid per Share	Total Number of Shares Purchased as Part of a Publicly Announced Plan	Maximum $ Amount of Shares that May Yet be Purchased Under a Plan (2)
4/01/2008-4/30/2008	484,586	$111.29	484,586	$823,171,647
5/01/2008-5/31/2008	543,970	$119.55	543,970	$787,829,847
6/01/2008-6/30/2008	770,543	$120.01	770,543	$707,627,695
Total	1,799,099	$117.52	1,799,099

(1)

In accordance with Entergy's stock-based compensation plans, Entergy periodically grants stock options to key employees that may be exercised to obtain shares of Entergy's common stock. According to the plans, these shares can be newly issued shares, treasury stock, or shares purchased on the open market. Entergy's management has been authorized by the Board to repurchase on the open market shares up to an amount sufficient to fund the exercise of grants under the plans. In addition to this authority, in January 2007 the Board approved a repurchase program under which Entergy is authorized to repurchase up to $1.5 billion of its common stock. The program does not have an expiration date, but Entergy expects to complete it in 2008. In January 2008, the Board authorized an incremental $500 million share repurchase program to enable Entergy to consider opportunistic purchases in response to equity market conditions. See Note 12 to the financial statements in the Form 10-K f or additional discussion of the stock-based compensation plans.

(2)

Maximum amount of shares that may yet be repurchased relates only to the $1.5 billion and $500 million plans and does not include an estimate of the amount of shares that may be purchased to fund the exercise of grants under the stock-based compensation plans.

The amount of share repurchases may vary as a result of material changes in business results or capital spending or new investment opportunities.

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Item 4. Submission of Matters to a Vote of Security Holders

Election of Board of Directors

Entergy Corporation

The annual meeting of stockholders of Entergy Corporation was held on May 2, 2008. The following matters were voted on and received the specified number of votes for, abstentions, votes withheld (against), and broker non-votes:

1. Election of Directors:

Name of Nominee	Votes For	Votes Against	Abstentions
Maureen S. Bateman	162,483,179	1,379,978	1,847,924
W. Frank Blount	159,924,086	3,980,608	1,806,387
Simon D. deBree	162,305,111	1,588,237	1,817,733
Gary W. Edwards	162,621,250	1,266,209	1,823,622
Alexis M. Herman	160,259,935	3,642,024	1,809,122
Donald C. Hintz	162,643,443	1,303,103	1,764,535
J. Wayne Leonard	162,777,353	1,146,413	1,787,315
Stuart L. Levenick	162,622,546	1,309,222	1,779,313
James R. Nichols	162,461,831	1,452,170	1,797,080
William A. Percy, II	162,366,184	1,550,470	1,794,427
W. J. "Billy" Tauzin	162,160,349	1,761,156	1,789,576
Steven V. Wilkinson	162,467,535	1,474,131	1,769,415

2. Ratify the appointment of independent public accountants, Deloitte & Touche LLP for the year 2008: 163,354,763 votes for; 849,674 votes against; and 1,506,644 abstentions.
    

3. Shareholder proposal relating to advisory vote on executive compensation: 57,885,138 votes for; 81,014,139 votes against; 13,435,872 abstentions; and 13,375,932 broker non-votes.
    

4. Shareholder proposal relating to limitations on management compensation: 8,781,863 votes for; 141,336,617 votes against; 2,201,540 abstentions; and 13,391,061 broker non-votes.
    

5. Shareholder proposal relating to corporate political contribution: 34,163,658 votes for; 86,778,857 votes against; 31,369,607 abstentions; and 13,398,959 broker non-votes.
    

6. Shareholder proposal relating to special shareholder meetings: 83,618,800 votes for; 66,298,271 votes against; 2,395,188 abstentions; and 13,398,822 broker non-votes.

Entergy Arkansas

A consent in lieu of a meeting of common stockholders was executed on June 9, 2008. The consent was signed on behalf of Entergy Corporation, the holder of all issued and outstanding shares of common stock. The common stockholder, by such consent, elected the following individuals to serve as directors constituting the Board of Directors of Entergy Arkansas: Hugh T. McDonald, Chairman, Leo P. Denault, Mark T. Savoff, and Gary J. Taylor.

Entergy Gulf States Louisiana

A consent in lieu of a meeting of common stockholders was executed on June 27, 2008. The consent was signed on behalf of EGS Holdings, Inc., the holder of all issued and outstanding shares of common stock. The common stockholder, by such consent, elected the following individuals to serve as directors constituting the Board of Directors of Entergy Gulf States Louisiana: E. Renae Conley, Chair, Leo P. Denault, Mark T. Savoff, and Gary J. Taylor.

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Entergy Louisiana

A consent in lieu of a meeting of members was executed on June 27, 2008. The consent was signed on behalf of Entergy Louisiana Holdings, Inc., the holder of all issued and outstanding common membership interests. The holder of the common membership interests, by such consent, elected the following individuals to serve as directors constituting the Board of Directors of Entergy Louisiana: E. Renae Conley, Chair, Leo P. Denault, Mark T. Savoff, and Gary J. Taylor.

Entergy Mississippi

A consent in lieu of a meeting of common stockholders was executed on June 9, 2008. The consent was signed on behalf of Entergy Corporation, the holder of all issued and outstanding shares of common stock. The common stockholder, by such consent, elected the following individuals to serve as directors constituting the Board of Directors of Entergy Mississippi: Carolyn C. Shanks, Chair, Leo P. Denault, Mark T. Savoff, Gary J. Taylor, and Haley R. Fisackerly. Effective July 13, 2008, Carolyn C. Shanks resigned as a director, chair of the board, and chief executive officer of Entergy Mississippi.

A consent in lieu of a meeting of common stockholders was executed on July 14, 2008. The consent was signed on behalf of Entergy Corporation, the holder of all issued and outstanding shares of common stock. The common stockholder, by such consent, elected the following individuals to serve as directors constituting the Board of Directors of Entergy Mississippi: Haley R. Fisackerly, Chairman, Leo P. Denault, Mark T. Savoff, and Gary J. Taylor.

Entergy New Orleans

A consent in lieu of a meeting of common stockholders was executed on June 9, 2008. The consent was signed on behalf of Entergy Corporation, the holder of all issued and outstanding shares of common stock. The common stockholder, by such consent, elected the following individuals to serve as directors constituting the Board of Directors of Entergy New Orleans: Roderick K. West, Chairman, Gary J. Taylor, Tracie L. Boutte, and William J. Burroughs.

Entergy Texas

A consent in lieu of a meeting of common stockholders was executed on June 9, 2008. The consent was signed on behalf of Entergy Corporation, the holder of all issued and outstanding shares of common stock. The common stockholder, by such consent, elected the following individuals to serve as directors constituting the Board of Directors of Entergy Texas: Joseph F. Domino, Chairman, Leo P. Denault, Mark T. Savoff, and Gary J. Taylor.

System Energy

A consent in lieu of a meeting of common stockholders was executed on June 27, 2008. The consent was signed on behalf of Entergy Corporation, the holder of all issued and outstanding shares of common stock. The common stockholder, by such consent, elected the following individuals to serve as directors constituting the Board of Directors of System Energy: Michael R. Kansler, Chairman, Steven C. McNeal, and Leo P. Denault.

Item 5. Other Information

Affiliate Purchased Power Agreements

See Part I, Item 1 of the Form 10-K for a discussion of the FERC proceeding involving the purchased power agreements entered by Entergy Louisiana and Entergy New Orleans to procure electric power from affiliates, the FERC's decision in the proceeding, and the LPSC's appeal of that decision. On April 10, 2008, the LPSC filed its initial brief with the D.C. Circuit. In its initial brief, the LPSC argues the FERC erred: (1) in concluding that Entergy Arkansas' short term sale of capacity and energy to third parties did not trigger the obligation to offer a right of first refusal

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with respect to this capacity to the other Utility operating companies pursuant to the provisions of the System Agreement; and (2) by approving an allocation of baseload generating resources that unduly preferred Entergy New Orleans and unduly discriminated against Entergy Gulf States Louisiana. The FERC's brief and the joint brief of the Utility operating companies, the APSC, the MPSC, and the City Council were filed in June 2008, and the LPSC filed its reply brief in July 2008.

Franchises and Certificates

As discussed in the Entergy Texas Form 10, on December 28, 2007, the Texas Industrial Energy Consumers (TIEC) filed a petition asking the PUCT to declare that Entergy Gulf States, Inc. was required to obtain prior PUCT approval in connection with Entergy Texas' acquisition of its certificate of convenience and necessity as part of the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Texas and Entergy Gulf States Louisiana.  The TIEC further requested that the PUCT declare Entergy Texas' acquisition of the certificate of convenience and necessity null and void if it occurred without prior PUCT approval.

To resolve expeditiously any outstanding related issues, on March 31, 2008, Entergy Texas filed a request with the PUCT for approval of the allocation to Entergy Texas of the certificate of convenience and necessity to the extent the PUCT finds such an approval is necessary. On May 8, 2008, the ALJ issued an order consolidating the TIEC proceeding discussed above with this proceeding because the filings share threshold issues. On May 16, 2008, the ALJ certified two issues for the PUCT to consider that relate to whether Entergy Gulf States, Inc. needed to obtain PUCT approval with regard to allocating its certificate of convenience and necessity to Entergy Texas. In June 2008 the PUCT determined that the legislation authorizing the completion of the jurisdictional separation of Entergy Gulf States, Inc. into two separate companies contemplated Entergy Texas' succession to Entergy Gulf States, Inc.'s rights under the certificate of convenience and necessity without further regulatory approval. The PUCT, however, has not issued a final order in this proceeding.

Environmental Regulation

Ozone Non-attainment

Entergy Texas and Entergy Gulf States Louisiana each operate fossil-fueled generating units in geographic areas that are not in attainment of the currently-enforced national ambient air quality standards for ozone. Texas non-attainment areas that affect Entergy are the Houston-Galveston and the Beaumont-Port Arthur areas. In Louisiana, Entergy is affected by the non-attainment status of the Baton Rouge area. Areas in non-attainment are classified as "marginal", "moderate," "serious," or "severe." When an area fails to meet the ambient air standard, the EPA requires state regulatory authorities to prepare state implementation plans meant to cause progress toward bringing the area into attainment with applicable standards.

In April 2004, the EPA issued a final rule, effective June 2005, revoking the 1-hour ozone standard, including designations and classifications. In a separate action over the same period, the EPA enacted 8-hour ozone non-attainment classifications and stated that areas designated as non-attainment under a new 8-hour ozone standard shall have one year to adjust to the new requirements with submittal of a new attainment plan. For Louisiana, the Baton Rouge area is currently classified as a ''marginal" (rather than "severe") non-attainment area under the new standard with an attainment date of June 15, 2007. On March 21, 2008 the EPA published a notice that the Baton Rouge area had failed to meet the standard by the attainment date and was proceeding with a "bump-up" of the area to the next higher non-attainment level. The Baton Rouge area is now classified as "moderate" non-attainment under the new standard with an attainment date of June 15, 2010.

For Texas, the Beaumont-Port Arthur area is currently classified as a "marginal" (rather than "serious") non-attainment area under the new standard with an attainment date of June 15, 2007. On March 18, 2008 the EPA published a notice that the Beaumont-Port Arthur area had failed to meet the standard by the attainment date based on the area's 2004-2006 monitoring data and was proceeding with a "bump-up" of the area to the next higher non-attainment level. The 2005-2007 monitoring data showed the area to be in attainment, however, and the TCEQ is considering a draft request to EPA for redesignation of the area from non-attainment to attainment under the 8-hour ozone standard. The Houston-Galveston area is now classified

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as "moderate" non-attainment under the new standard with an attainment date of June 15, 2010. On June 15, 2007, the Texas governor petitioned the EPA to reclassify the Houston-Galveston area from "moderate" to "severe" with an attainment date of June 15, 2019. EPA consideration of the petition is still pending.

In December 2006, the EPA's revocation of the 1-hour ozone standard was rejected by the courts. As a result, numerous requirements can return for areas that fail to meet 1-hour ozone levels by dates set by the law. These requirements include the potential to increase fees significantly for plants operating in these areas. In addition, it is possible that new emission controls may be required. Specific costs of compliance cannot be estimated at this time, but Entergy is monitoring development of the respective state implementation plans and will develop specific compliance strategies as the plans move through the adoption process.

On March 12, 2008 the EPA reduced the National Ambient Air Quality Standard for ozone, which will in turn place additional counties and parishes in which Entergy operates in nonattainment status. States will develop State Implementation Plans that outline control requirements to enable these counties and parishes to reach attainment status. Entergy facilities in these areas will be subject to installation of NOx controls, but the degree of control will not be known until the State Implementation Plans are developed. Entergy will monitor and be involved in the State Implementation Plans development process in states where Entergy has facilities.

Interstate Air Transport

In March 2005, the EPA finalized the Clean Air Interstate Rule, which would have reduced SO₂ and NOx emissions from electric generation plants in order to address transport issues and improve air quality in 29 eastern states. The Clean Air Interstate Rule was vacated by the U.S. Court of Appeals for the D.C. Circuit on July 11, 2008. The court found that the EPA failed to address basic obligations under the Clean Air Act's "good neighbor" provision regarding "upwind" states' contribution to air quality impairment in "downwind" states. Entergy is currently evaluating the impact of the D.C. Circuit's decision on both state plans to assure compliance with National Ambient Air Quality Standards and on the regional haze program, discussed below, because the regional haze program regulations rely in part on reductions expected to be gained thro ugh the Clean Air Interstate Rule program.

Regional Haze

In June 2005, the EPA issued final Best Available Retrofit Control Technology (BART) regulations, which could potentially result in a requirement to install SO₂ pollution control technology on certain of Entergy's coal and oil generation units. The rule leaves certain BART determinations to the states. The Arkansas Department of Environmental Quality (ADEQ) has completed its State Implementation Plan for Arkansas facilities to implement its obligations under the Clean Air Visibility Rule. The ADEQ has determined that Entergy Arkansas' White Bluff power plant affects Class I Area visibility and will be subject to the EPA's presumptive BART requirements to install scrubbers and low NOx burners by 2013. Under current regulations, the scrubbers must be operational by September 2013. The project remains in the planning stages and has not been fully designed, but the latest conceptual cost estimate has gone up significantly from previous estimates d ue to increases in equipment, commodity, and labor costs. These estimates indicate that Entergy Arkansas' share of the project could cost approximately $630 million compared to the $375 million reported in the Form 10-K. Entergy continues to review potential environmental spending needs and financing alternatives for any such spending, and future spending estimates could change based on the results of this continuing analysis.

316(b) Cooling Water Intake Structures

In March 2008, the NYDEC issued a draft water quality certification and a draft discharge permit for FitzPatrick, opening a 30-day public comment period on these documents. The certification, or a waiver or exemption of the same, is required by section 401 of the federal Clean Water Act as a supporting document to the NRC's license renewal decision. The discharge permit action is not related to the license renewal decision. The NYDEC received comments on the draft documents from Entergy and from the public, and New York law requires that a hearing now be held on these public comments prior to the issuance of a final discharge permit or water quality certification. In response, the NYDEC issued a draft denial without prejudice of the certification. FitzPatrick, having filed a timely and complete application for permit renewal, has continued to operate under its

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administratively continued discharge permit. On July 16, 2008, negotiations with the state concerning issuance of these authorizations resulted in an agreement, memorialized in a stipulation executed by the state and Entergy on July 17, 2008. The agreement includes a voluntary commitment by Entergy to install ristroph screens and an initial fish return system during the next five-year permit cycle. Additionally, Entergy has agreed to conduct further studies regarding the feasibility and effectiveness of relocating the facility's offshore intake structure and of additional fish return technologies. The permit to be issued under the agreement requires that NYDEC initiate a permit modification (triggering Entergy's right to challenge) if the state decides to require the installation and operation of additional fish return technology. The NYDEC issued the water permit as described above and issued the water quality certification. Additionally, the New York Department of State has iss ued the Coastal Zone Management consistency determination, also required for the NRC to complete the licensing process.

Vermont Yankee Thermal Discharge Permit

Opposition groups appealed a final permit issued to Vermont Yankee pursuant to the National Pollutant Discharge Elimination System in which the Vermont Agency of Natural Resources (VANR) allowed a small increase in the amount of heat the facility can discharge to the Connecticut River from June 16 to October 14 each year. The VANR permit increases operational flexibility for the required usage rate of the existing cooling towers and for the generation rate of the facility that is especially helpful in conditions of high ambient temperatures or low river flow conditions. The trial of this matter took place in the Vermont Environmental Court during the summer of 2007. On May 22, 2008, the Court ruled that Vermont Yankee may operate with the increased thermal discharge from July 8 to October 14 of each year, and may operate with the increased thermal discharge from June 16 to July 7 as long as the discharge does not raise the water temperature above 76.7 degrees Fahrenheit at a certain location downstream. Vermont Yankee and VANR are working to develop specific permit conditions that reflect the court's order. Opposition groups have announced that they will appeal the decision to the Vermont Supreme Court.

Indian Point 2 Hazardous Waste Remediation

As part of the effort to terminate the current Indian Point 2 mixed waste storage permit, Entergy was required to perform groundwater and soil sampling for metals, PCB's and other non-radiological contaminants on plant property, regardless of whether these contaminants stem from onsite activities or were related to the waste stored on-site pursuant to the permit. Entergy believes this permit is no longer necessary for the facility due to an exemption for mixed wastes (hazardous waste that is also radioactive) recently promulgated as part of EPA's hazardous waste regulations. This exemption allows mixed waste to be regulated through the NRC license instead of through a separate EPA or state hazardous waste permit. In February 2008, Entergy submitted its report on this sampling effort to the NYDEC. The report indicated the presence of various metals in soils at levels above the NYDEC cleanup objectives. It does not appear that these metals are connected to operation of the nuclear f acility. NYDEC is now requiring that Entergy submit a plan by August 9, 2008 for a study that will identify the sources of the metals, define the vertical and lateral extent of the contamination on-site, and evaluate the potential for migration off-site. The NYDEC plans to use the results of this investigation to determine whether the permit can be terminated and the metals left in place until plant decommissioning or if further investigation or remediation is required. Entergy is unable to determine what the extent or cost of required remediation, if any, will be at this time.

Executive Stock Ownership Guidelines

In July 2008, the Personnel Committee of the Board adopted Stock Ownership Guidelines, including an equity retention policy, for officers of Entergy Corporation and its subsidiaries. The guidelines are intended to more closely align key executives' interests with the interests of Entergy Corporation's shareholders. To comply with these guidelines, officers must satisfy one of the two following conditions:

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Stock Ownership Guidelines. The officer must achieve and maintain targeted ownership levels of Entergy Corporation common stock. The market value of common stock held must at least meet the following multiple of the officer's base salary:

Officer's Management Level	Multiple of Base Salary
Level 1	5
Level 2	4
Level 3	2.5
Level 4	1.5

; or

Equity Retention Policy. The officer must retain at least 75 percent of the after-tax net profit realized from the exercise of any stock option granted on or after January 1, 2003, in the form of Entergy common stock, until the earlier of (A) 60 months from the date on which the option is exercised or (B) the termination of the officer's full-time employment with Entergy Corporation or an affiliate.

Shares of Entergy Corporation common stock held by the officer directly, restricted stock and restricted stock units, and shares held by the officer in employee savings plans are counted toward satisfaction of the requirements.

The Personnel Committee will review compliance with the policy annually.

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

The Registrant Subsidiaries have calculated ratios of earnings to fixed charges and ratios of earnings to combined fixed charges and preferred dividends/distributions pursuant to Item 503 of Regulation S-K of the SEC as follows:

	Ratios of Earnings to Fixed Charges
	Twelve Months Ended
	December 31,					June 30,
	2003	2004	2005	2006	2007	2008
Entergy Arkansas	3.17	3.37	3.75	3.37	3.19	3.20
Entergy Gulf States Louisiana	1.51	3.04	3.34	3.01	2.84	2.95
Entergy Louisiana	3.93	3.60	3.50	3.23	3.44	3.68
Entergy Mississippi	3.06	3.41	3.16	2.54	3.22	3.33
Entergy New Orleans	1.73	3.60	1.22	1.52	2.74	3.35
Entergy Texas	1.21	2.07	2.06	2.12	2.07	2.60
System Energy	3.66	3.95	3.85	4.05	3.95	3.66

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	Ratios of Earnings to Combined Fixed Charges and Preferred Dividends/Distributions
	Twelve Months Ended
	December 31,					June 30,
	2003	2004	2005	2006	2007	2008
Entergy Arkansas	2.79	2.98	3.34	3.06	2.88	2.86
Entergy Gulf States Louisiana	1.45	2.90	3.18	2.90	2.73	2.88
Entergy Louisiana	-	-	-	2.90	3.08	3.26
Entergy Mississippi	2.77	3.07	2.83	2.34	2.97	3.06
Entergy New Orleans	1.59	3.31	1.12	1.35	2.54	3.07

Item 6. Exhibits *

4(a) -	Seventy-sixth Supplemental Indenture, dated as of May 1, 2008, to Entergy Gulf States Louisiana's Indenture of Mortgage, dated as of September 1, 1926.
4(b) -	Sixty-seventh Supplemental Indenture, dated as of July 1, 2008, to Entergy Arkansas's Mortgage and Deed of Trust, dated as of October 1, 1944.
10(a) -	Entergy Corporation Service Recognition Program For Non-Employee Outside Directors (As Amended and Restated Effective January 1, 2009).
10(b) -	Entergy Corporation Outside Director Stock Program Established under the 2007 Equity Ownership and Long Term Cash Incentive Plan of Entergy Corporation and Subsidiaries (Amended and Restated Effective January 1, 2009).
12(a) -	Entergy Arkansas' Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Dividends, as defined.
12(b) -	Entergy Gulf States Louisiana's Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Distributions, as defined.
12(c) -	Entergy Louisiana's Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Distributions, as defined.
12(d) -	Entergy Mississippi's Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Dividends, as defined.
12(e) -	Entergy New Orleans' Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Dividends, as defined.
12(f) -	Entergy Texas' Computation of Ratios of Earnings to Fixed Charges, as defined.
12(g) -	System Energy's Computation of Ratios of Earnings to Fixed Charges, as defined.
31(a) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Corporation.
31(b) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Corporation.
31(c) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Arkansas.
31(d) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Arkansas. 145
31(e) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Gulf States Louisiana.
31(f) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Gulf States Louisiana.
31(g) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Louisiana.
31(h) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Louisiana.
31(i) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Mississippi.
31(j) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Mississippi.
31(k) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy New Orleans.
31(l) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy New Orleans.
31(m) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Texas.
31(n) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Texas.
31(o) -	Rule 13a-14(a)/15d-14(a) Certification for System Energy.
31(p) -	Rule 13a-14(a)/15d-14(a) Certification for System Energy.
32(a) -	Section 1350 Certification for Entergy Corporation.
32(b) -	Section 1350 Certification for Entergy Corporation.
32(c) -	Section 1350 Certification for Entergy Arkansas.
32(d) -	Section 1350 Certification for Entergy Arkansas.
32(e) -	Section 1350 Certification for Entergy Gulf States Louisiana.
32(f) -	Section 1350 Certification for Entergy Gulf States Louisiana.
32(g) -	Section 1350 Certification for Entergy Louisiana.
32(h) -	Section 1350 Certification for Entergy Louisiana.
32(i) -	Section 1350 Certification for Entergy Mississippi.
32(j) -	Section 1350 Certification for Entergy Mississippi.
32(k) -	Section 1350 Certification for Entergy New Orleans.
32(l) -	Section 1350 Certification for Entergy New Orleans.
32(m) -	Section 1350 Certification for Entergy Texas.
32(n) -	Section 1350 Certification for Entergy Texas.
32(o) -	Section 1350 Certification for System Energy.
32(p) -	Section 1350 Certification for System Energy.

___________________________

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Pursuant to Item 601(b)(4)(iii) of Regulation S-K, Entergy Corporation agrees to furnish to the Commission upon request any instrument with respect to long-term debt that is not registered or listed herein as an Exhibit because the total amount of securities authorized under such agreement does not exceed ten percent of the total assets of Entergy Corporation and its subsidiaries on a consolidated basis.

*	Reference is made to a duplicate list of exhibits being filed as a part of this report on Form 10-Q for the quarter ended June 30, 2008, which list, prepared in accordance with Item 102 of Regulation S-T of the SEC, immediately precedes the exhibits being filed with this report on Form 10-Q for the quarter ended June 30, 2008.
**	Incorporated herein by reference as indicated.

147

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, each registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature for each undersigned company shall be deemed to relate only to matters having reference to such company or its subsidiaries.

ENTERGY CORPORATION
ENTERGY ARKANSAS, INC.
ENTERGY GULF STATES LOUISIANA, L.L.C.
ENTERGY LOUISIANA, LLC
ENTERGY MISSISSIPPI, INC.
ENTERGY NEW ORLEANS, INC.
ENTERGY TEXAS, INC.
SYSTEM ENERGY RESOURCES, INC.

                   /s/ Theodore H. Bunting, Jr.                         
Theodore H. Bunting, Jr.
Senior Vice President and Chief Accounting Officer
(For each Registrant and for each as
Principal Accounting Officer)

Date: August 7, 2008

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EX-4

Exhibit 4(a)

ENTERGY GULF STATES LOUISIANA, L.L.C.
(Successor by merger to Entergy Gulf States, Inc., formerly Gulf States Utilities Company)

446 North Boulevard
Baton Rouge, Louisiana 70802-5717

TO

THE BANK OF NEW YORK
(Successor to JPMorgan Chase Bank, N.A.)
as Trustee

101 Barclay Street
New York, New York 10286

__________________

Seventy-sixth Supplemental Indenture

Dated as of May 1, 2008

__________________

Relating to an Issue of First Mortgage Bonds,
6.000% Series due May 1, 2018
and Supplementing Indenture of Mortgage
dated September 1, 1926

__________________

THIS INSTRUMENT GRANTS A SECURITY
INTEREST BY A UTILITY

THIS INSTRUMENT CONTAINS AFTER-ACQUIRED
PROPERTY PROVISIONS

THIS SEVENTY-SIXTH SUPPLEMENTAL INDENTURE, dated as of the 1^st day of May, 2008, by and between ENTERGY GULF STATES LOUISIANA, L.L.C. (successor by merger to Entergy Gulf States, Inc., formerly Gulf States Utilities Company, a Texas corporation hereinafter sometimes called the Predecessor Company), a limited liability company duly organized and existing under the laws of the State of Louisiana (hereinafter sometimes called the Company), party of the first part, and THE BANK OF NEW YORK (successor to JPMorgan Chase Bank, N.A.), a New York banking corporation and having its corporate trust office in the Borough of Manhattan, City and State of New York, as successor trustee under the Indenture of Mortgage and indentures supplemental thereto hereinafter mentioned (hereinafter sometimes called the Trustee), party of the second part;

WITNESSETH: THAT

WHEREAS, the Predecessor Company has heretofore executed and delivered its Indenture of Mortgage, dated September 1, 1926 (hereinafter sometimes called the Original Indenture), to The Chase National Bank of the City of New York, as trustee, in and by which the Predecessor Company conveyed and mortgaged to said The Chase National Bank of the City of New York, as trustee, certain property, therein described, to secure the payment of its bonds issued and to be issued under said Original Indenture in one or more series, as therein provided; and

WHEREAS, the Predecessor Company has heretofore executed and delivered to The Chase National Bank of the City of New York, as trustee, the First through the Fourth Supplemental Indentures, all supplementing and modifying said Original Indenture; and

WHEREAS, on March 21, 1939, The Chase National Bank of the City of New York resigned as trustee under the Original Indenture and all indentures supplemental thereto as aforesaid, pursuant to Section 4 of Article XIV of the Original Indenture, and by an Indenture dated March 21, 1939 said resignation was accepted and Central Hanover Bank and Trust Company was duly appointed the successor trustee under the Original Indenture and all indentures supplemental thereto, said resignation and appointment both being effective as of March 21, 1939, and the Central Hanover Bank and Trust Company did by said Indenture dated March 21, 1939 accept the trust under the Original Indenture and all indentures supplemental thereto; and

WHEREAS, the Predecessor Company has heretofore executed and delivered to Central Hanover Bank and Trust Company, as successor trustee, the Fifth through the Tenth Supplemental Indentures, supplementing and modifying said Original Indenture; and

WHEREAS, the name of Central Hanover Bank and Trust Company, successor trustee, as aforesaid, was changed effective June 30, 1951 to "The Hanover Bank"; and

WHEREAS, the Predecessor Company has heretofore executed and delivered to The Hanover Bank, as successor trustee, the Eleventh through the Twentieth Supplemental Indentures, supplementing and modifying said Original Indenture; and

WHEREAS, on September 8, 1961, pursuant to the laws of the State of New York, The Hanover Bank, successor trustee, as aforesaid, was duly merged into Manufacturers Trust Company, a New York corporation, under the name "Manufacturers Hanover Trust Company," and Manufacturers Hanover Trust Company thereupon became the duly constituted successor trustee under the Original Indenture, as supplemented and modified as aforesaid; and

WHEREAS, the Predecessor Company has heretofore executed and delivered to Manufacturers Hanover Trust Company, as successor trustee, the Twenty-first through the Fifty-fourth Supplemental Indentures, supplementing and modifying said Original Indenture; and

WHEREAS, on June 19, 1992, pursuant to the laws of the State of New York, Manufacturers Hanover Trust Company, successor trustee, as aforesaid, was duly merged into Chemical Bank, a New York corporation, under the name "Chemical Bank," and Chemical Bank thereupon became the duly constituted successor trustee under the Original Indenture, as supplemented and modified as aforesaid; and

WHEREAS, the Predecessor Company has heretofore executed and delivered to Chemical Bank, as successor trustee, the Fifty-fifth through the Fifty-seventh Supplemental Indentures, supplementing and modifying said Original Indenture; and

WHEREAS, the name of Chemical Bank, successor trustee, as aforesaid, was duly merged with and changed effective July 14, 1996 to The Chase Manhattan Bank; and

WHEREAS, the Predecessor Company has heretofore executed and delivered to The Chase Manhattan Bank, as successor trustee, the Fifty-eighth through Sixtieth Supplemental Indentures supplementing and modifying said Original Indenture; and

WHEREAS, the name of The Chase Manhattan Bank, successor trustee, as aforesaid, was duly changed effective November 10, 2001 to JPMorgan Chase Bank; and

WHEREAS, the Predecessor Company has heretofore executed and delivered to JPMorgan Chase Bank, as successor trustee, the Sixty-first through Sixty-seventh Supplemental Indentures supplementing and modifying said Original Indenture; and

WHEREAS, effective November 13, 2004, JPMorgan Chase Bank, successor trustee, was converted from a New York corporation to a national banking association under the name "JPMorgan Chase Bank, N.A."; and

WHEREAS, the Predecessor Company has heretofore executed and delivered to JPMorgan Chase Bank, N.A., as successor trustee, the Sixty-eighth through Seventy-fourth Supplemental Indentures supplementing and modifying said Original Indenture; and

WHEREAS, on October 3, 2007, JPMorgan Chase Bank, N.A. resigned as trustee under the Original Indenture and all indentures supplemental thereto as aforesaid, by an Agreement of Resignation, Appointment and Acceptance dated October 3, 2007, said resignation was accepted, and The Bank of New York was duly appointed the successor trustee under the Original Indenture and all indentures supplemental thereto, said resignation and appointment both being effective as of October 3, 2007, and The Bank of New York did by said Agreement dated October 3, 2007 accept the trust under the Original Indenture and all indentures supplemental thereto; and

WHEREAS, the series of bonds established under the Seventh Supplemental Indenture supplementing and modifying said Original Indenture and under each successive supplemental indenture have been designated respectively and are referred to herein as "Bonds of the 1976, 1978, 1979, 1980, 1981, 1982, 1983, 1986, 1987, 1988, 1989, 1989A, 1990, 1992, 1996, 1997, 1998, 1998A, 1999, 1999A, 2000, 2000A, 2001, 2003, 2004, 2005, 2006, 2007, 2009, 2009A, 1987A, 2010, 1991, 1993, 1992A, 2012, 2013, 2013A, 1994, 2014B, C and D, 2015, 2016, 2016A, 1994A, 2002, 2022, 2004A, 2024, 1996A, 1997A, 1998B, 1999B, 2003A, MTN, 2003B, 2004B, 2007A, 2012A, 2008, 2007B, 2033, 2015A, 2011, 2009B, 2014E, 2035, 2015B, 2010A, 2006A, 2008A and 2011B Series"; and

WHEREAS, effective as of December 26, 2007, the Predecessor Company obtained the release from the lien of the Original Indenture, as supplemented and modified of all of its real property located in Texas and substantially all of its personal property located in Texas that was part of the trust estate, together with certain associated rights, privileges and franchises, as well as certain undivided interests in mortgaged property located in Louisiana, as more particularly described in the instruments of partial release filed with respect thereto on or before December 26, 2007; and

WHEREAS, effective as of 1:00 P.M. Central Standard Time, December 31, 2007, the Predecessor Company underwent a merger by division under Texas law pursuant to which, among other things, all of its property located in Texas, together with certain property located in Louisiana, was allocated to Entergy Texas, Inc., substantially all of its property located in Louisiana was retained by the Predecessor Company, and all of its obligations and liabilities under the Original Indenture, as supplemented and modified and the Bonds were retained by the Predecessor Company; and

WHEREAS, effective as of 4:00 P.M. Central Standard Time, December 31, 2007, (hereinafter sometimes called the Effective Time) the Predecessor Company merged (hereinafter sometimes called the Merger) into the Company pursuant to an Agreement and Plan of Merger and Reorganization of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana, L.L.C. and a Certificate and Articles of Merger (hereinafter sometimes collectively called the Merger Documents), pursuant to which, among other things, (1) all of the rights, privileges, franchises, assets, liabilities and obligations of the Predecessor Company were allocated to the Company; and (2) the identity of the Predecessor Company was merged into that of the Company; and

WHEREAS, pursuant to Section 14.01 of the Original Indenture, as restated by the Seventh Supplemental Indenture, the Company and the Trustee executed the Seventy-fifth Supplemental Indenture dated as of December 31, 2007 whereby the Company assumed and agreed to pay duly and punctually the principal of and interest on the Bonds issued under the Original Indenture, as supplemented and modified in accordance with the provisions of said Bonds and the Original Indenture, as supplemented and modified, and agreed to perform and fulfill all the terms, covenants and conditions of the Original Indenture, as supplemented and modified binding the Predecessor Company; and

WHEREAS, pursuant to Section 14.02 of the Original Indenture, as restated by the Seventh Supplemental Indenture, the Company has succeeded to the Predecessor Company under the Original Indenture and all indentures supplemental thereto with the same effect as if it had been named in the Original Indenture, as supplemented and modified, as the mortgagor company and in the Bonds as the obligor thereon or maker thereof;

WHEREAS, pursuant to Section 14.03 of the Original Indenture, as restated by the Seventh Supplemental Indenture, in respect of property owned by the Predecessor Company at the time of the Merger as provided in Section 14.01 of the Original Indenture, as restated by the Seventh Supplemental Indenture, and substitutions, replacements, additions, betterments, developments, extensions and enlargements thereto subsequently made, constructed or acquired, the rights and duties of the Company shall be the same as the rights and duties of the Predecessor Company would have been had the Merger not taken place; and

WHEREAS, pursuant to Section 14.04 of the Original Indenture, as restated by the Seventh Supplemental Indenture, in respect of property at the time of the Merger owned by the Company and/or of property thereafter acquired by the Company except said substitutions, replacements, additions, betterments, developments, extensions and enlargements to, of or upon the property owned by the Predecessor Company referred to in Section 14.03 of the Original Indenture, as restated by the Seventh Supplemental Indenture, the Original Indenture, as supplemented and modified shall not become or be a lien upon any of such property; and

WHEREAS, effective as of March 25, 2008, the Company obtained the release from the lien of the Original Indenture, as supplemented and modified of all of the remainder of its property located in Texas that was part of the trust estate, together with certain associated rights, privileges and franchises, as well as certain undivided interests in mortgaged property located in Louisiana, as more particularly described in the instruments of partial release filed with respect thereto on or before March 25, 2008; and

WHEREAS, under the Original Indenture, as supplemented and modified, any new series of Bonds may at any time be established by the Board of Directors of the Company and the terms thereof may be specified by a supplemental indenture executed by the Company and the Trustee; and

WHEREAS, the Company proposes to create under the Original Indenture, as supplemented and modified as aforesaid and as further supplemented by this Seventy-sixth Supplemental Indenture (the Original Indenture as so supplemented and modified being hereinafter sometimes called the Indenture), a new series of Bonds to be designated First Mortgage Bonds, 6.000% Series due May 1, 2018, such Bonds when originally issued to be dated May 16, 2008 and to mature on May 1, 2018 (hereinafter sometimes referred to as the Bonds of the 2018 Series, and presently to issue $375,000,000 aggregate principal amount of the Bonds of the 2018 Series; and

WHEREAS, all acts and proceedings required by law and by the Restated Articles of Incorporation and Bylaws of the Company necessary to make the Bonds of the 2018 Series, when executed by the Company, authenticated and delivered by the Trustee and duly issued, the valid, binding and legal obligations of the Company, and to constitute the Indenture a valid and binding mortgage for the security of all the Bonds of the Company issued or to be issued under the Indenture, in accordance with its and their terms, have been done and taken; and the execution and delivery of this Seventy-sixth Supplemental Indenture have been in all respects duly authorized;

NOW, THEREFORE, THIS SEVENTY-SIXTH SUPPLEMENTAL INDENTURE WITNESSETH:

That in order to secure the payment of the principal of, premium, if any, and interest on, all Bonds at any time issued and outstanding under the Indenture, according to their tenor, purport and effect, and to secure the performance and observance of all the covenants and conditions in said Bonds and in the Indenture contained, and to declare the terms and conditions upon and subject to which the Bonds of the 2018 Series are and are to be issued and secured, and for and in consideration of the premises and of the mutual covenants herein contained and of the acceptance of the Bonds of the 2018 Series by the holders thereof, and of the sum of $1 duly paid to the Company by the Trustee, at or before the execution and delivery hereof, and for other valuable consideration, the receipt whereof is hereby acknowledged, the Company has executed and delivered this Seventy-sixth Supplemental Indenture, and by these presents does grant, bargain, sell, alienate, remise, release, convey, assign, transfe r, mortgage, hypothecate, pledge, set over and confirm unto the Trustee, its successors in trust and assigns, the following property, rights, privileges and franchises hereinafter described, acquired or constructed by the Company after the Effective Time to the extent constituting substitutions, replacements, additions, betterments, developments, extensions or enlargements to, of or upon the trust estate allocated to the Company by the Merger Documents, together in each case with any substitutions, replacements, additions, betterments, developments, extensions and enlargements thereto, thereof or thereupon subsequently made, constructed or acquired by the Company (other than excepted property as hereinafter defined):

CLAUSE I.

All and singular the lands, real estate, chattels real, interests in land, leaseholds, ways, rights of way, grants, easements, servitudes, rights pursuant to ordinances, consents, permits, patents, licenses, lands under water, water and riparian rights, franchises, privileges, immunities, rights to construct, maintain and operate distribution and transmission systems, all other rights and interests, gas, water, steam and electric light, heat and power plants and systems, dams, and dam sites, stations and substations, powerhouses, electric transmission and distribution lines and systems, pipe lines, conduits, towers, poles, wires, cables and all other structures, machinery, engines, boilers, dynamos, motors, transformers, generators, electric and mechanical appliances, office buildings, warehouses, garages, stables, sheds, shops, tunnels, subways, bridges, other buildings and structures, implements, tools and other apparatus, appurtenances and facilities, materials and supplies, and all oth er property of any nature appertaining to any of the plants, systems, business or operations of the Company, whether or not affixed to the realty, used in the operation of any of the premises or plants or systems, or otherwise, allocated to the Company by the Merger Documents or constituting substitutions, replacements, additions, betterments, developments, extensions or enlargements to, of or upon the trust estate allocated to the Company by the Merger Documents (other than excepted property as hereinafter defined); including (but not limited to) all its properties situated in the Cities of Baton Rouge, Jennings and Lake Charles and in the Parishes of Acadia, Allen, Ascension, Beauregard, Calcasieu, Cameron, East Baton Rouge, East Feliciana, Iberia, Iberville, Jefferson Davis, Lafayette, Livingston, Pointe Coupee, St. Helena, St. Landry, St. Martin, St. Tammany, Tangipahoa, Vermilion, Washington, West Baton Rouge and West Feliciana, Louisiana, and vicinity allocated to the Company by the Merger Documents or constituting substitutions, replacements, additions, betterments, developments, extensions or enlargements to the trust estate allocated to the Company by the Merger Documents (other than excepted property as hereinafter defined).

CLAUSE II.

All corporate, Federal, State, county (parish), municipal and other permits, consents, licenses, bridge licenses, bridge rights, river permits, franchises, patents, rights pursuant to ordinances, grants, privileges and immunities of every kind and description allocated to the Company by the Merger Documents or constituting substitutions, replacements, additions, betterments, developments, extensions or enlargements to, of or upon the trust estate allocated to the Company by the Merger Documents (other than excepted property as hereinafter defined).

CLAUSE III.

Also all other property, real, personal or mixed, tangible or intangible of every kind, character and description, allocated to the Company by the Merger Documents or constituting substitutions, replacements, additions, betterments, developments, extensions or enlargements to, of or upon the trust estate allocated to the Company by the Merger Documents (other than excepted property as hereinafter defined), whether or not useful in the generation, manufacture, production, transportation, distribution, sale or supplying of electricity, steam, water or gas.

CLAUSE IV.

PROPERTIES EXCEPTED.

There is, however, expressly excepted and excluded from the lien and operation of this Indenture (1) all "excepted property" as defined and described in Granting Clause VII of the Original Indenture, as restated by the Seventh Supplemental Indenture, (omitting from such exception specifically described property thereafter expressly subjected to the lien of the Indenture), (2) all property owned by the Company prior to the Merger and (3) all property acquired by the Company after the Merger not constituting substitutions, replacements, additions, betterments, developments, extensions or enlargements to, of or upon the trust estate allocated to the Company by the Merger Documents.

TO HAVE AND TO HOLD the trust estate and all and singular the lands, properties, estates, rights, franchises, privileges and appurtenances hereby mortgaged, hypothecated, conveyed, pledged or assigned, or intended so to be, together with all the appurtenances thereto appertaining and the rents, issues and profits thereof, unto the Trustee and its successors in trust and to its assigns, forever.

SUBJECT, HOWEVER, to the exceptions (except as omitted above in Clause IV hereof), reservations, restrictions, conditions, limitations, covenants and matters recited in Article Twenty of the Indenture, and in each respective Article Three of the Eighth and each consecutive succeeding Supplemental Indenture through the Seventeenth Supplemental Indenture and, likewise, of the Nineteenth through the Thirty-seventh Supplemental Indentures and, likewise, of the Thirty-ninth through the Fifty-seventh Supplemental Indentures or contained in any deeds and other instruments whereunder the Company has acquired any of the property now owned by it, to permitted encumbrances as defined in Subsection B of Section 1.07 of the Indenture, and, with respect to any property which the Company may hereafter acquire, to all terms, conditions, agreements, covenants, exceptions and reservations expressed or provided in the deeds or other instruments, respectively, under and by virtue of which the Company shall he reafter acquire the same and to any liens thereon existing, and to any liens for unpaid portions of the purchase money placed thereon, at the time of such acquisition.

BUT, IN TRUST, NEVERTHELESS, for the equal and proportionate use, benefit, security and protection of those who from time to time shall hold the Bonds and coupons, if any, authenticated and delivered under the Indenture and duly issued by the Company, without any discrimination, preference or priority of any one Bond or coupon, if any, over any other by reason of priority in the time of issue, sale or negotiation thereof or otherwise, except as provided in Section 12.28 of the of the Original Indenture, as restated by the Seventh Supplemental Indenture, so that, subject to said Section 12.28 of the Original Indenture, as restated by the Seventh Supplemental Indenture, each and all of said Bonds and coupons, if any, shall have the same right, lien and privilege under the Indenture and shall be equally secured thereby and shall have the same proportionate interest and share in the trust estate, with the same effect as if all the Bonds and coupons, if any, had been issued, sold and negotiated simultaneously.

AND UPON THE TRUSTS, USES AND PURPOSES and subject to the covenants, agreements and conditions of the Original Indenture as modified and supplemented by previous supplemental indentures and by this Seventy-sixth Supplemental Indenture.

1. Bonds of the 2018 Series and
   Certain Provisions Relating Thereto.

   1.  
      1. Terms of Bonds of the 2018 Series. There is hereby established a new series of Bonds to be issued under and secured by the Indenture, to be known as and entitled "First Mortgage Bonds, 6.000% Series due May 1, 2018". The principal amount of the Bonds of the 2018 Series shall not be limited except as provided in Section 3.01 of the Indenture, and except as may otherwise be provided in an indenture supplemental to the Indenture. The definitive Bonds of the 2018 Series shall be registered Bonds without coupons of the denominations of $1,000 and in multiples of $1,000 in excess thereof as shall be authorized by written order of the Company, numbered R-1 consecutively upwards. Bonds of the 2018 Series may be issued in the first instance (until definitive Bonds to be issued in exchange therefor are prepared and ready for delivery) as temporary Bonds dated May 16, 2008, in denominations of $1,000 and of such multiples of $1,000 as shall have been authorized, as aforesaid, numbered TR-1 consecutively upwards, in substantially the form of Bond set forth in Section 1.01C of this Seventy-sixth Supplemental Indenture, with changes therein appropriate to their character.

         Initially, the Bonds of the 2018 Series offered and sold to Qualified Institutional Buyers (within the meaning of Rule 144A under the Securities Act) in reliance on such Rule 144A shall be issued in the form of a definitive global bond with the depository legend, the non-registration legend and the registration rights legend set forth in the form of Bond set forth herein (the "Rule 144A Global Bond"). Initially, the Bonds of the 2018 Series offered and sold in reliance on Regulation S under the Securities Act shall be issued in the form of a temporary global bond with the depository legend, the Regulation S legend and the registration rights legend set forth in the form of Bond set forth herein (the "Temporary Regulation S Global Bond" and, together with the Pe rmanent Regulation S Global Bond (as defined herein) and the Rule 144A Global Bond, the "Global Bonds"). The Global Bonds shall be deposited with The Depository Trust Company ("DTC") or its custodian and registered in the name of DTC or its nominee, duly executed by the Company and authenticated by the Trustee as provided herein and in the Original Indenture. The aggregate principal amount of each Global Bond may from time to time be increased or decreased by adjustments made on such Global Bonds or in the records of the Trustee or DTC or its nominee as hereinafter provided.

         Transfers of beneficial interests in the Rule 144A Global Bond will be subject to the restrictions on transfer contained in the non-registration legend set forth in the form of Bond set forth in Section 1.01C of this Seventy-sixth Supplemental Indenture. Prior to the expiration of the period of 40 consecutive days beginning on and including the later of (x) the day on which the offering of the Bonds of the 2018 Series commences and (y) the original issue date of the Bonds of the 2018 Series (the "Distribution Compliance Period"), transfers of beneficial interests in the Temporary Regulation S Global Bond will be subject to the restrictions on transfer contained in the Regulation S legend set forth in the form of Bond set forth in Section 1.01C of this Seventy-sixth Supplemental Indenture. At any time after the expiration of the Distribution Compliance Period, upon receipt by the Trustee and the Company of a certificate from Euroclear or Clearstream certifying that it has receiv ed certification of non-U.S. beneficial ownership of a Temporary Regulation S Global Bond (or portion thereof) with respect to any Bonds of the 2018 Series to be exchanged, one or more separate definitive global bonds (each, a "Permanent Regulation S Global Bond" and, together with the Temporary Regulation S Global Bond, each, a "Regulation S Global Bond") shall be duly executed by the Company and authenticated by the Trustee as provided herein and in the Original Indenture, shall be registered in the name of DTC or its nominee, and shall include the depository legend and the registration rights legend set forth in Exhibit A hereto and shall be deposited with DTC or its custodian. The Trustee, as custodian for DTC, shall reflect by endorsement thereon a decrease in the principal amount of the Temporary Regulation S Global Bond in an amount equal to the principal amount of such Temporary Regulation S Global Bond exchanged. Prior to the expiration of the Distribution Compliance Period, be neficial interests in any Temporary Regulation S Global Bond may only be held through Euroclear and Clearstream. After the expiration of the Distribution Compliance Period, transfers of beneficial interests in the Permanent Regulation S Global Bond will not be subject to any restrictions.

         If a holder of a beneficial interest in a Rule 144A Global Bond wishes at any time to transfer such interest to a person who wishes to take delivery thereof in the form of a beneficial interest in a Regulation S Global Bond, or if a holder of a beneficial interest in a Regulation S Global Bond wishes at any time to transfer such interest to a person who wishes to take delivery thereof in the form of a beneficial interest in a Rule 144A Global Bond, upon receipt by the Trustee of (A) written instructions given in accordance with the rules and procedures of DTC (together with, as applicable, the rules and procedures of Euroclear and Clearstream, the "Applicable Procedures") from the applicable participant directing DTC to cause to be credited to another account of a participant a beneficial interest in such Regulation S Global Bond or Rule 144A Global Bond (as the case may be) equal to that of the beneficial interest in such Rule 144A Global Bond or Regulation S Global Bond (as the case may be) to be so transferred, (B) a written order given in accordance with the Applicable Procedures containing information regarding such other account, as well as the account of Euroclear or Clearstream (as the case may be) for which such other account is held, to be credited with, and the account of such applicable participant to be debited for, such beneficial interest and (C) a certificate satisfactory to the Company and the Trustee, as to such transfer's compliance with any transfer or other restrictions relating to such Global Bond, given by the transferor of such beneficial interest, the Trustee shall (1) reduce or increase (as the case may be) the principal amount of such Rule 144A Global Bond, and increase or reduce (as the case may be) the principal amount of such Regulation S Global Bond, in each case by an amount equal to the principal amount of the beneficial interest in such Rule 144A Global Bond or Regulation S Global Bond (as the case may be) to be so transferred, as evidenced on the records of the Trustee and by an endorsement on each such Global Bond and (2) cause DTC to credit and debit such beneficial interests to the respective accounts specified in the instructions referred to above.

         Bonds of the 2018 Series shall be dated as provided in Section 3.05 of the Indenture. Notwithstanding the provisions of said Section 3.05, so long as there is no default in the payment of interest on Bonds of the 2018 Series existing at the time of the authentication hereinafter referred to, all Bonds of the 2018 Series authenticated by the Trustee between the record date (as hereinafter defined in this section) for any interest payment date for Bonds of the 2018 Series and such interest payment date shall be dated the date of and shall bear interest from such interest payment date; provided, however, that if and to the extent the Company shall default in the payment of such interest due on such interest payment date, then any such Bond of the 2018 Series shall bear interest from the interest payment date next preceding the date of such Bond of the 2018 Series. The Bonds of the 2018 Series shall mature on May 1, 2018, and, beginning on May 16, 2008, shall bear interest at the r ate of 6.000% per annum until the payment of the principal thereof, such interest to be payable semiannually on May 1 and November 1 in each year, commencing November 1, 2008, and on the maturity date. If the Company does not comply with certain of its obligations under the Registration Rights Agreement (as defined below), the Bonds of the 2018 Series shall, in accordance with Section 2(e) of the Registration Rights Agreement, bear additional interest ("Additional Interest") in addition to the interest provided for in the immediately preceding sentence. For purposes of this Seventy-sixth Supplemental Indenture and the Bonds of the 2018 Series, the term "interest" shall be deemed to include interest provided for in the second immediately preceding sentence and Additional Interest, if any. If any interest payment date for the Bonds of the 2018 Series falls on a day that is not a Business Day, the interest payment date will be the next succeeding Business Day, and no inter est on such payment shall accrue for the period from and after the interest payment date. If the maturity date or any redemption date of the Bonds of the 2018 Series falls on a day that is not a Business Day, the payment of principal and interest (to the extent payable with respect to the principal being redeemed if on a redemption date) will be made on the next succeeding Business Day, and no interest on such payment shall accrue for the period from and after the maturity date or such redemption date. Interest on the Bonds of the 2018 Series will be calculated on the basis of a 360-day year comprised of twelve 30-day months.

         The person in whose name any Bond of the 2018 Series is registered on any record date with regard to any interest payment date shall be entitled to receive the interest payable thereon on such interest payment date notwithstanding the cancellation of such Bond upon any transfer or exchange thereof subsequent to such record date and prior to such interest payment date, unless the Company shall default in the payment of the interest due on such interest payment date, in which case such defaulted interest shall be paid to the person in whose name such Bond is registered on the date of payment of such defaulted interest. The term "record date" as used in this Section with regard to any interest payment date shall mean the close of business on the Business Day next preceding such interest payment date. Both principal of and interest on the Bonds of the 2018 Series will be paid in any coin or currency of the United States of America which at the time of payment is legal tender for th e payment of public and private debts, at the corporate trust office in the Borough of Manhattan, City and State of New York, of the Trustee.

         The definitive Bonds of the 2018 Series may be issued in the form of Bonds engraved, printed, lithographed, or partly engraved and partly printed or lithographed, on steel engraved borders or typed.

         Upon compliance with the provisions of Section 3.10 of the Indenture and upon payment, at the option of the Company, of the charges provided in Section 3.11 of the Indenture, subject to the provisions of any legend set forth thereon, Bonds of the 2018 Series may be exchanged for a new Bond or Bonds of the said Series of different authorized denominations of like aggregate principal amount.

         The Trustee hereunder shall, by virtue of its office as such Trustee, be the registrar and transfer agent of the Company for the purpose of registering and transferring Bonds of the 2018 Series.

         The Company has entered into a Registration Rights Agreement dated as of May 16, 2008 (the "Registration Rights Agreement") with the initial purchasers of the Bonds of the 2018 Series pursuant to which the Bonds of the 2018 Series that are issued and sold without registration (the "Private Bonds of the 2018 Series") under the Securities Act of 1933, as amended (the "Securities Act"), may be exchanged for Bonds of the 2018 Series that will be registered under the Securities Act and that will otherwise have substantially the same terms as the Private Bonds of the 2018 Series (the "Exchange Bonds of the 2018 Series"), or, failing such exchange, the Company has agreed to file a shelf registration statement for the resale of the Private Bonds of the 2018 Series. The Private Bonds of the 2018 Series will be offered and sold by the Company in reliance on an exemption from registration under the Securities Act, and Private Bonds of the 2018 Series will be exchanged for Exchange Bonds of the 2018 Series only pursuant to an effective registration statement under the Securities Act and otherwise in accordance with the Registration Rights Agreement and the Indenture. The Private Bonds of the 2018 Series and the Exchange Bonds of the 2018 Series will constitute a single series of bonds under the Indenture. Exchange Bonds of the 2018 Series shall be authenticated and delivered by the Trustee at one time or from time to time upon the written order or orders of the Company in principal amounts equal to the principal amounts of the Private Bonds of the 2018 Series surrendered in exchange therefor.

      2. Form of Bonds of the 2018 Series. The Bonds of the 2018 Series, and the Trustee's authentication certificate to be executed on the Bonds of the 2018 Series, shall be in substantially the following forms, respectively:

      [FORM OF FACE OF BOND OF THE 2018 SERIES]

      [depository legend to be included on Bonds of the 2018 Series]

      Unless this Certificate is presented by an authorized representative of The Depository Trust Company, a New York corporation ("DTC"), to the Company or its agent for registration of transfer, exchange, or payment, and any certificate issued is registered in the name of Cede & Co. or in such other name as is requested by an authorized representative of DTC (and any payment is made to Cede & Co. or to such other entity as is requested by an authorized representative of DTC), ANY TRANSFER, PLEDGE, OR OTHER USE HEREOF FOR VALUE OR OTHERWISE BY OR TO ANY PERSON IS WRONGFUL inasmuch as the registered owner hereof, Cede & Co., has an interest herein.

      [non-registration legend to be included on Private Bonds of the 2018 Series]

      THIS SECURITY (OR PREDECESSOR) WAS ORIGINALLY ISSUED IN A TRANSACTION EXEMPT FROM REGISTRATION UNDER THE SECURITIES ACT OF 1933, AS AMENDED (THE "SECURITIES ACT"), AND THIS SECURITY MAY NOT BE OFFERED, SOLD OR OTHERWISE TRANSFERRED IN THE ABSENCE OF SUCH REGISTRATION OR AN APPLICABLE EXEMPTION THEREFROM OR A TRANSACTION NOT SUBJECT THERETO. EACH PURCHASER OF THIS SECURITY IS HEREBY NOTIFIED THAT THE SELLER OF THIS SECURITY MAY BE RELYING ON THE EXEMPTION FROM THE PROVISIONS OF SECTION 5 OF THE SECURITIES ACT PROVIDED BY RULE 144A THEREUNDER.

      THE HOLDER OF THIS SECURITY AGREES FOR THE BENEFIT OF THE COMPANY THAT (A) THIS SECURITY MAY BE OFFERED, RESOLD, PLEDGED OR OTHERWISE TRANSFERRED PRIOR TO THE DATE WHICH IS ONE YEAR (OR SIX MONTHS IF ALL APPLICABLE CONDITIONS TO SUCH RESALE UNDER RULE 144 UNDER THE SECURITIES ACT (OR ANY SUCCESSOR PROVISION THEREOF) ARE SATISFIED) AFTER THE LATER OF THE ORIGINAL ISSUANCE DATE THEREOF, AND THE LAST DATE ON WHICH THE COMPANY OR ANY AFFILIATE THEREOF WAS THE OWNER OF THIS SECURITY OR THE EXPIRATION OF SUCH SHORTER PERIOD AS MAY BE PRESCRIBED BY SUCH RULE 144 (OR SUCH SUCCESSOR PROVISION) PERMITTING RESALES OF THIS SECURITY WITHOUT ANY CONDITIONS (THE "RESALE RESTRICTION TERMINATION DATE"), ONLY (I) TO THE COMPANY, (II) INSIDE THE UNITED STATES TO A PERSON WHOM THE SELLER REASONABLY BELIEVES IS A "QUALIFIED INSTITUTIONAL BUYER" (AS DEFINED IN RULE 144A UNDER THE SECURITIES ACT) IN A TRANSACTION MEETING THE REQUIREMENTS OF RULE 144A, (III) OUTSIDE THE UNITED STATES IN A TRAN SACTION COMPLYING WITH THE PROVISIONS OF RULE 903 OR RULE 904 UNDER THE SECURITIES ACT, (IV) PURSUANT TO AN EXEMPTION FROM REGISTRATION UNDER THE SECURITIES ACT PROVIDED BY RULE 144 THEREUNDER (IF AVAILABLE) OR PURSUANT TO ANY OTHER AVAILABLE EXEMPTION FROM THE REGISTRATION REQUIREMENTS OF, OR IN A TRANSACTION NOT SUBJECT TO, THE SECURITIES ACT OR (V) PURSUANT TO AN EFFECTIVE REGISTRATION STATEMENT UNDER THE SECURITIES ACT, IN EACH OF CLAUSES (I) THROUGH (V) IN ACCORDANCE WITH ANY APPLICABLE SECURITIES LAWS OF ANY STATE OF THE UNITED STATES, AND (B) THE HOLDER WILL, AND EACH SUBSEQUENT HOLDER IS REQUIRED TO, NOTIFY ANY SUBSEQUENT PURCHASER OF THIS SECURITY FROM IT OF THE RESALE RESTRICTIONS REFERRED TO IN CLAUSE (A) ABOVE. THE FOREGOING RESTRICTIONS ON RESALE WILL NOT APPLY SUBSEQUENT TO THE RESALE RESTRICTION TERMINATION DATE. THE HOLDER OF THIS SECURITY ACKNOWLEDGES THAT THE COMPANY RESERVES THE RIGHT PRIOR TO ANY OFFER, SALE OR OTHER TRANSFER (1) PURSUANT TO CLAUSE (IV) PRIOR TO THE RESALE RESTRICTION T ERMINATION DATE TO REQUIRE THE DELIVERY OF AN OPINION OF COUNSEL, CERTIFICATIONS OR OTHER INFORMATION SATISFACTORY TO THE COMPANY AND (2) IN EACH OF THE FOREGOING CASES, TO REQUIRE THAT A CERTIFICATE AS TO COMPLIANCE WITH CERTAIN CONDITIONS TO TRANSFER IS COMPLETED AND DELIVERED BY THE TRANSFEROR TO THE COMPANY.

      [Regulation S legend to be included on Private Bonds of the 2018 Series]

      THIS SECURITY IS REPRESENTED BY A TEMPORARY REGULATION S GLOBAL BOND WITHIN THE MEANING OF THE SEVENTY-SIXTH SUPPLEMENTAL INDENTURE HEREINAFTER REFERRED TO. BY ITS ACQUISITION HEREOF, EACH HOLDER OF THIS SECURITY, AND EACH PERSON THAT ACQUIRES A BENEFICIAL INTEREST IN SUCH SECURITY, AGREES THAT PRIOR TO THE EXPIRATION OF THE DISTRIBUTION COMPLIANCE PERIOD (AS DEFINED IN REGULATION S UNDER THE SECURITIES ACT), BENEFICIAL INTERESTS IN THIS SECURITY MAY ONLY BE OFFERED, RESOLD OR OTHERWISE TRANSFERRED (A) INSIDE THE UNITED STATES TO A QUALIFIED INSTITUTIONAL BUYER IN COMPLIANCE WITH RULE 144A UNDER THE SECURITIES ACT OF 1933 OR (B) OUTSIDE THE UNITED STATES IN COMPLIANCE WITH RULE 903 OR 904 UNDER THE SECURITIES ACT OF 1933 AND, IN EACH CASE, IN ACCORDANCE WITH ANY APPLICABLE SECURITIES LAWS OF THE STATES OF THE UNITED STATES OR ANY OTHER APPLICABLE JURISDICTION.

      [registration rights legend to be included on Bonds of the 2018 Series]

      BY ITS ACCEPTANCE OF THE SECURITIES EVIDENCED HEREBY OR A BENEFICIAL INTEREST IN SUCH SECURITIES, THE HOLDER OF, AND ANY PERSON THAT ACQUIRES A BENEFICIAL INTEREST IN, SUCH SECURITIES AGREES TO BE BOUND BY THE PROVISIONS OF THE REGISTRATION RIGHTS AGREEMENT DATED AS OF MAY 16, 2008 AND RELATING TO THE REGISTRATION UNDER THE SECURITIES ACT OF SECURITIES EXCHANGEABLE FOR THE SECURITIES EVIDENCED HEREBY AND REGISTRATION OF THE SECURITIES EVIDENCED HEREBY.

      No. R-___ CUSIP _______________

      ENTERGY GULF STATES LOUISIANA, L.L.C.
      FIRST MORTGAGE BOND, 6.000% SERIES
      DUE MAY 1, 2018

      ENTERGY GULF STATES LOUISIANA, L.L.C., a Louisiana limited liability company (hereinafter sometimes called the "Company"), for value received, hereby promises to pay to _____________________, or registered assigns, the principal amount set forth on Schedule I hereto on May 1, 2018, and to pay interest thereon from May 16, 2008, if the date of this bond is prior to November 1, 2008, or, if the date of this bond is on or after November 1, 2008, from the May 1 or November 1 immediately preceding the date of this bond to which interest has been paid (unless the date hereof is an interest payment date to which interest has been paid, in which case from the date hereof) at the rate of 6.000% per annum, on May 1 and November 1 of each year, commencing November 1, 2008, and at maturity or earlier redemption, until payment of the principal hereof. If the Company does not comply with certain of its obligations under the Registration Rights Agr eement, this bond shall, in accordance with Section 2(e) of the Registration Rights Agreement, bear additional interest ("Additional Interest") in addition to the interest provided for in the immediately preceding sentence. For purposes of this bond, the term "interest" shall be deemed to include interest provided for in the second immediately preceding sentence and Additional Interest, if any. The interest so payable on any May 1 or November 1 will be paid to the person in whose name this bond is registered at the close of business on the Business Day next preceding such interest payment date, unless the Company shall default in the payment of the interest due on such interest payment date, in which case such defaulted interest shall be paid to the person in whose name this bond is registered on the date of payment of such defaulted interest. If any interest payment date for this bond falls on a day that is not a Business Day, the payment of interest will be made on the next succeeding Business Day, and no interest on such payment shall accrue for the period from and after the interest payment date. If the maturity date or any redemption date of this bond falls on a day that is not a Business Day, the payment of principal and interest (to the extent payable with respect to the principal being redeemed if on a redemption date) will be made on the next succeeding Business Day, and no interest on such payment shall accrue for the period from and after the maturity date or such redemption date.

      Both principal of and interest on this bond will be paid in any coin or currency of the United States of America which at the time of payment is legal tender for the payment of public and private debts, at the corporate trust office in the Borough of Manhattan, City and State of New York, of the Trustee under the Indenture.

      This bond shall not become or be valid or obligatory for any purpose until the authentication certificate hereon shall have been signed by the Trustee.

      The provisions of this bond are continued on the reverse hereof and such continued provisions shall for all purposes have the same effect as though fully set forth at this place.

      IN WITNESS WHEREOF, Entergy Gulf States Louisiana, L.L.C. has caused these presents to be executed in its corporate name, by facsimile signature or manually, by its President or one of its Vice Presidents and by its Treasurer or an Assistant Treasurer under its corporate seal or a facsimile thereof, all as of ______________, 200__.

      ENTERGY GULF STATES LOUISIANA, L.L.C.

      By:
      Vice President and Treasurer

      And By:
      Assistant Treasurer

      [SEAL]

      [FORM OF REVERSE OF BOND OF THE 2018 SERIES]
      
      ENTERGY GULF STATES LOUISIANA, L.L.C.
      FIRST MORTGAGE BOND, 6.000% SERIES
      DUE MAY 1, 2018 (Continued)

      This bond is one of the bonds, of the above designated series, of an authorized issue of bonds of the Company, known as First Mortgage Bonds, issued or issuable in one or more series under and equally secured (except insofar as any sinking and/or improvement fund or other fund established in accordance with the provisions of the Indenture hereinafter mentioned may afford additional security for the bonds of any specific series) by an Indenture of Mortgage dated September 1, 1926, as supplemented and modified by indentures supplemental thereto, to and including a Seventy-sixth Supplemental Indenture dated as of December 1, 2005 to The Bank of New York, as Trustee, to which Indenture of Mortgage, as so supplemented and modified, and all indentures supplemental thereto (herein sometimes called the Indenture) reference is hereby made for a description of the property mortgaged and pledged as security for said bonds, the nature and extent of the security, and the rights, duties and immunities t hereunder of the Trustee, the rights of the holders of said bonds and of the Trustee and of the Company in respect of such security, and the terms upon which said bonds may be issued thereunder.

      This bond is redeemable as provided in the Indenture, including the right of the Company to give notice of redemption conditioned upon its deposit of funds provided for in the Seventy-sixth Supplemental Indenture with respect to this series.

      The Indenture contains provisions permitting the Company and the Trustee, with the consent of the holders of not less than seventy-five percent in principal amount of the bonds (exclusive of the bonds disqualified by reason of the Company's interest therein) at the time outstanding, including, if more than one series of bonds shall be at the time outstanding, not less than sixty percent in principal amount of each series affected, to effect, by an indenture supplemental to the Indenture, modifications or alterations of the Indenture and of the rights and obligations of the Company and of the holders of the bonds; provided, however, that no such modification or alteration shall be made without the written approval or consent of the registered owner hereof which will (a) extend the maturity of this bond or reduce the rate or extend the time of payment of interest hereon or reduce the amount of the principal hereof, or (b) permit the creation of any lien, not otherwise permitted, prior to or on a parity with the lien of the Indenture, or (c) reduce the percentage of the principal amount of the bonds upon the approval or consent of the holders of which modifications or alterations may be made as aforesaid.

      This bond is transferable by the registered owner hereof in person or by his duly authorized attorney at the corporate trust office in the Borough of Manhattan, City and State of New York, of the Trustee upon surrender of this bond for cancellation and upon payment, if the Company shall so require, of the charges provided for in the Indenture, and thereupon a new registered bond of the same series of like principal amount will be issued to the transferee in exchange therefor.

      The registered owner of this bond, at the option of said owner, may surrender the same for cancellation at said office and receive in exchange therefor the same aggregate principal amount of bonds of the same series but of other authorized denominations, upon payment, if the Company shall so require, of the charges provided for in the Indenture and subject to the terms and conditions therein set forth.

      If a default as defined in the Indenture shall occur, the principal of this bond may become or be declared due and payable before maturity in the manner and with the effect provided in the Indenture. The holders, however, of certain specified percentages of the bonds at the time outstanding, including in certain cases specified percentages of bonds of particular series, may in those cases, to the extent and under the conditions provided in the Indenture, waive certain defaults thereunder and the consequences of such defaults.

      No recourse shall be had for the payment of the principal of or the interest on this bond, or for any claim based hereon, or otherwise in respect hereof or of the Indenture, against any incorporator, shareholder, director or officer, past, present or future, as such, of the Company or of any predecessor or successor corporation, either directly or through the Company or such predecessor or successor corporation, under any constitution or statute or rule of law, or by the enforcement of any assessment or penalty, or otherwise, all such liability of incorporators, shareholders, directors and officers, as such, being waived and released by the holder and owner hereof by the acceptance of this bond and as provided in the Indenture.

      [FORM OF TRUSTEE'S AUTHENTICATION CERTIFICATE FOR BONDS]
      
      TRUSTEE'S AUTHENTICATION CERTIFICATE

      This is one of the bonds, of the series designated therein, described in the within-mentioned Indenture.

      THE BANK OF NEW YORK
        As Trustee

      By:
      Authorized Officer

      SCHEDULE I

      GLOBAL CERTIFICATE

      The initial principal amount of Securities evidenced by this global certificate is

      $________________

      CHANGES TO PRINCIPAL AMOUNT OF SECURITIES EVIDENCED

      BY GLOBAL CERTIFICATE

      Date Principal Amount of Securities by which this Global Certificate is to be Reduced or Increased, and Reason for Reduction of Increase Remaining Principal Amount of Securities Represented by this Global Certificate Notation Made by

   2. Redemption Provisions for Bonds of the 2018 Series.  The Bonds of the 2018 Series shall be redeemable at the option of the Company, in whole or in part, prior to maturity, upon notice (which redemption may be made subject to the deposit of the redemption moneys with the Trustee prior to the date designated for redemption) mailed to each registered owner at its last address appearing on the bond register not less than 30 days nor more than 60 days prior to the date fixed for redemption, (i) at any time prior to maturity, at a redemption price equal to the greater of (a) 100% of the principal amount of such Bonds of the 2018 Series to be redeemed and (b) as determined by the Independent Investment Banker, the sum of (x) the present value of the payment on the redemption date of the principal amount of such Bonds of the 2018 Series to be redeemed plus (y) the sum of the present values of the remaining scheduled payments of interest on such Bonds of the 2018 Series to be redeemed to maturity (excluding the portion of any such interest accrued to such redemption date), discounted (for purposes of determining such present values) to such redemption date on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Adjusted Treasury Rate plus 0.40% plus accrued and unpaid interest thereon to such redemption date.

      Adjusted Treasury Rate shall mean, with the respect to any redemption date:

      (1) the yield, under the heading which represents the average for the immediately preceding week, appearing in the most recently published statistical release designated "H.15(519)" or any successor publication which is published weekly by the Board of Governors of the Federal Reserve System and which establishes yields on actively traded United States Treasury securities adjusted to constant maturity under the caption "Treasury Constant Maturities," for the maturity corresponding to the Comparable Treasury Issue (if no maturity is within three months before or after the remaining term of the Bonds of the 2018 Series, yields for the two published maturities most closely corresponding to the Comparable Treasury Issue shall be determined and the Adjusted Treasury Rate shall be interpolated or extrapolated from such yields on a straight line basis, rounding to the nearest month); or

      (2) if such release (or any successor release) is not published during the week preceding the calculation date for the Adjusted Treasury Rate or does not contain such yields, the rate per annum equal to the semi-annual equivalent yield to maturity of the Comparable Treasury Issue, calculated using a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such redemption date.

      The Adjusted Treasury Rate shall be calculated on the third Business Day preceding the redemption date.

      Business Day shall mean any day other than a Saturday or a Sunday or a day on which banking institutions in The City of New York, New York are authorized or required by law or executive order to remain closed or a day on which the corporate trust office of the Trustee is closed for business.

      Comparable Treasury Issue shall mean the United States Treasury security selected by the Independent Investment Banker as having a maturity comparable to the remaining term of the Bonds of the 2018 Series that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term of the Bonds of the 2018 Series.

      Comparable Treasury Price shall mean, with respect to any redemption date, (i) the average of five Reference Treasury Dealer Quotations for such redemption date after excluding the highest and lowest such Reference Treasury Dealer Quotations or (ii) if the Independent Investment Banker obtains fewer than five such Reference Treasury Dealer Quotations, the average of all such Reference Treasury Dealer Quotations.

      Independent Investment Banker shall mean one of the Reference Treasury Dealers, that the Company appoints to act as the Independent Investment Banker from time to time, or, if any of such firms is unwilling or unable to select the Comparable Treasury Issue, an independent investment banking institution of national standing appointed by the Company.

      Reference Treasury Dealer shall mean (i) Morgan Stanley & Co. Incorporated, Greenwich Capital Markets, Inc., Mizuho Securities USA Inc. and their respective successors; provided, however, that if any of the foregoing shall cease to be a primary U.S. Government securities dealer in New York City (a "Primary Treasury Dealer"), the Company shall substitute therefor another Primary Treasury Dealer, and (ii) any other Primary Treasury Dealer selected by the Independent Banker after consultation with the Company.

      Reference Treasury Dealer Quotations shall mean, with respect to each Reference Treasury Dealer and any redemption date, the average, as determined by the Independent Investment Banker, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to the Independent Investment Banker at 5:00 p.m. on the third Business Day preceding such redemption date.

   3. Duration of Effectiveness of Article One.  Sections 1.01 through 1.02 of this article shall be of force and effect only so long as any Bonds of the 2018 Series are outstanding.
2. This Seventy-sixth Supplemental Indenture is executed and shall be construed as an indenture supplemental to the Original Indenture as supplemented and modified. As heretofore supplemented and modified, and as supplemented hereby, the Original Indenture is in all respects ratified and confirmed, and the Original Indenture, as heretofore supplemented and modified, and this Seventy-sixth Supplemental Indenture shall be read, taken and construed as one and the same instrument.

   The recitals in this Seventy-sixth Supplemental Indenture are made by the Company only and not by the Trustee; and all of the provisions contained in the Original Indenture as supplemented and modified, in respect to the rights, privileges, immunities, powers and duties of the Trustee shall be applicable in respect hereof as fully and with like effect as if set forth herein in full.

   Although this Seventy-sixth Supplemental Indenture is dated for convenience and for the purpose of reference as of May 1, 2008, the actual date or dates of execution by the Company and by the Trustee are as indicated by their respective acknowledgements hereto annexed.

   In order to facilitate the recording or filing of this Seventy-sixth Supplemental Indenture, the same may be simultaneously executed in several counterparts and each shall be deemed to be an original and such counterparts shall together constitute one and the same instrument.

The words "herein", "hereof", "hereunder" and other words of similar import refer to this Seventy-sixth Supplemental Indenture. All other terms used in this Supplemental Indenture shall be taken to have the same meaning as in the Original Indenture and indentures supplemental thereto, except in cases where the context clearly indicates otherwise.

IN TESTIMONY WHEREOF, ENTERGY GULF STATES LOUISIANA, L.L.C. has caused these presents to be executed in its name and behalf by its President or a Vice President and its company seal to be hereunto affixed or a facsimile thereof printed hereon and attested by its Secretary or an Assistant Secretary, and THE BANK OF NEW YORK, in token of its acceptance hereof, has likewise caused these presents to be executed in its name and behalf by its President or a Vice President and its corporate seal to be hereunto affixed and attested by a Vice President, an Assistant Vice President or a Trust Officer, each in the presence of the respective undersigned Notaries Public, and of the respective undersigned competent witnesses, as of the day and year first above written.

ENTERGY GULF STATES LOUISIANA, L.L.C.

By: /s/ Steven C. McNeal
Steven C. McNeal
Vice President and Treasurer

(COMPANY SEAL)

Attest:

/s/ Dawn A. Abuso
Dawn A. Abuso
Assistant Secretary

/s/ Jennifer Favalora
Jennifer Favalora, Notary Public No. 57639
Parish of Orleans, State of Louisiana
My Commission is for life

Signed in the presence of:

/s/ Shannon K. Ryerson
Shannon K. Ryerson

/s/ Sylvia S. Higgins
Sylvia S. Higgins

THE BANK OF NEW YORK

By: /s/ Remo J. Reale
Remo J. Reale
Vice President

Attest:

/s/ Beata Hryniewicka
Beata Hryniewicka
Assistant Vice President

Before me

/s/ Carlos R. Luciano
Carlos R. Luciano
Notary Public, State of New York
No. 41-4765897
Qualified in Queens County
Commission Expires April 30, 2010

Signed, sealed and delivered in the presence of:

/s/ Franca Ferrera
Franca Ferrera

/s/ Maria Acosta
Maria Acosta

ENTERGY GULF STATES LOUISIANA, L.L.C.

United States of America,
State of Louisiana,                                     ss:
Parish of Orleans

I, the undersigned, a Notary Public duly qualified, commissioned, sworn and acting in and for the Parish and State aforesaid, hereby certify that, on this 14th day of May, 2008:

Before me personally appeared STEVEN C. McNEAL, Vice President and Treasurer, and DAWN A. ABUSO, Assistant Secretary, of Entergy Gulf States Louisiana, L.L.C., both of whom are known to me to be the persons whose names are subscribed to the foregoing instrument and both of whom are known to me to be Vice President and Treasurer, and Assistant Secretary, respectively, of said ENTERGY GULF STATES LOUISIANA, L.L.C., and separately acknowledged to me that they executed the same in the capacities therein stated for the purposes and considerations therein expressed and as the act and deed of ENTERGY GULF STATES LOUISIANA, L.L.C.

Before me personally came STEVEN C. McNEAL, to me known, who being by me duly sworn, did depose and say, that he resides in Mandeville, Louisiana; that he is Vice President and Treasurer of ENTERGY GULF STATES LOUISIANA, L.L.C., one of the corporations described in and which executed the above instrument; that he knows the seal of said corporation; that the seal affixed to or printed on said instrument is such corporate seal; that it was so affixed by order of the Board of Directors of said corporation, and that he signed his name thereto by like order.

BE IT REMEMBERED, that before me, and in the presence of Shannon K. Ryerson and Sylvia S. Higgins, competent witnesses, residing in said State, personally came and appeared STEVEN C. McNEAL and DAWN A. ABUSO, Vice President and Treasurer, and Assistant Secretary, respectively, of ENTERGY GULF STATES LOUISIANA, L.L.C., a limited liability company created by and existing under the laws of the State of Louisiana, with its Louisiana domicile in the City of Baton Rouge, Louisiana, and said STEVEN C. McNEAL and DAWN A. ABUSO declared and acknowledged to me, Notary, in the presence of the witnesses aforesaid, that they signed, executed and sealed the foregoing indenture for and on behalf of and in the name of ENTERGY GULF STATES LOUISIANA, L.L.C., and have affixed the corporate seal of said Company to the same or caused it to be printed thereon, by and with the authority of the Board of Directors of said Company.

GIVEN UNDER MY HAND AND SEAL OF OFFICE this 14th day of May, 2008.

(Notarial Seal)

/s/ Jennifer Favalora
Jennifer Favalora, Notary Public No. 57639
Parish of Orleans, State of Louisiana
My Commission is for Life.

United States of America,
State of New York,                             ss:
County of New York,

I, the undersigned, a Notary Public duly qualified, commissioned, sworn and acting in and for the County and State aforesaid, hereby certify that, on this 15th day of May , 2008:

Before me personally appeared Remo Reale, a Vice President of THE BANK OF NEW YORK, and Beata Hryniewicka, an Assistant Vice President, both of whom are known to me to be the persons whose names are subscribed to the foregoing instrument and both of whom are known to me to be a Vice President and an Assistant Vice President, respectively, of THE BANK OF NEW YORK, and separately acknowledged to me that they executed the same in the capacities therein stated for the purposes and consideration therein expressed, and as the act and deed of THE BANK OF NEW YORK.

Before me personally came Remo Reale, to me known, who being by me duly sworn, did depose and say, that he resides in Garden City, New York; that he is a Vice President of THE BANK OF NEW YORK, one of the entities described in and which executed the above instrument; that he knows the seal of said entity; that the seal affixed to said instrument is such corporate seal; that it was so affixed by order of the Board of Directors of said entity, and that he signed his name thereto by like order.

BE IT REMEMBERED, that before me, and in the presence of Franca Ferrera and Maria Acosta, competent witnesses, residing in said state, personally came and Remo Reale and Beata Hryniewicka, a Vice President and an Assistant Vice President, respectively, of THE BANK OF NEW YORK, a national banking association organized under the laws of the United States with a corporate trust office in the City of New York, New York, and said Vice President and Assistant Vice President, declared and acknowledged to me, Notary, in the presence of the witnesses aforesaid that they signed, executed and sealed the foregoing indenture for and on behalf of and in the name of THE BANK OF NEW YORK, and have affixed the corporate seal of THE BANK OF NEW YORK to the same by and with the authority of the Board of Directors of THE BANK OF NEW YORK.

GIVEN UNDER MY HAND AND SEAL OF OFFICE this 15th day of May, 2008.

(Notarial Seal)

 /s/ Carlos R. Luciano
Carlos R. Luciano
Notary Public, State of New York
No. 41-4765897
Qualified in Queens County
Commission Expires April 30, 2010

EX-4

Exhibit 4(b)

ENTERGY ARKANSAS, INC.

TO

DEUTSCHE BANK TRUST COMPANY AMERICAS

(successor to Guaranty Trust Company of New York)

AND

STANLEY BURG

(successor to Henry A. Theis)

AND

(as to property, real or personal, situated or being in Missouri)

THE BANK OF NEW YORK MELLON TRUST COMPANY,
NATIONAL ASSOCIATION

(successor to Marvin A. Mueller)

As Trustees under Entergy Arkansas, Inc.'s Mortgage and Deed of Trust,
Dated as of October 1, 1944

___________________________

SIXTY-SEVENTH SUPPLEMENTAL INDENTURE

Providing among other things for
First Mortgage Bonds, 5.40% Series due August 1, 2013 (Seventy-fourth Series)

__________________________

Dated as of July 1, 2008

SIXTY-SEVENTH SUPPLEMENTAL INDENTURE

INDENTURE, dated as of July 1, 2008, between ENTERGY ARKANSAS, INC., a corporation of the State of Arkansas, whose post office address is 425 West Capitol, Little Rock, Arkansas 72201 (hereinafter sometimes called the "Company"), and DEUTSCHE BANK TRUST COMPANY AMERICAS (successor to Guaranty Trust Company of New York), a New York banking corporation, whose post office address is 60 Wall Street, MS NYC 60-2710, New York, New York 10005 (hereinafter sometimes called the "Corporate Trustee"), and STANLEY BURG (successor to Henry A. Theis) (hereinafter sometimes called the "Co-Trustee"), and (as to property, real or personal, situated or being in Missouri) THE BANK OF NEW YORK MELLON TRUST COMPANY, NATIONAL ASSOCIATION (successor to Marvin A. Mueller), whose mailing address is 10161 Centurion Parkway, Jacksonville, Florida 32256 (said The Bank of New York Mellon Trust Company, National Association being hereinafter sometimes called the "Missouri Co-Trust ee" and the Corporate Trustee, the Co-Trustee and the Missouri Co-Trustee being hereinafter together sometimes called the "Trustees"), as Trustees under the Mortgage and Deed of Trust, dated as of October 1, 1944 (hereinafter sometimes called the "Mortgage"), which Mortgage was executed and delivered by the Company to secure the payment of bonds issued or to be issued under and in accordance with the provisions of the Mortgage, reference to which Mortgage is hereby made, this indenture (hereinafter called the "Sixty-seventh Supplemental Indenture") being supplemental thereto.

WHEREAS, the Mortgage was appropriately filed or recorded in various official records in the States of Arkansas, Missouri, Tennessee and Wyoming; and

WHEREAS, an instrument, dated as of July 7, 1949, was executed by the Company appointing Herbert E. Twyeffort as Co-Trustee in succession to Henry A. Theis (resigned) under the Mortgage, and by Herbert E. Twyeffort accepting said appointment, and said instrument was appropriately filed or recorded in various official records in the States of Arkansas, Missouri, Tennessee and Wyoming; and

WHEREAS, an instrument, dated as of March 1, 1960, was executed by the Company appointing Grainger S. Greene as Co-Trustee in succession to Herbert E. Twyeffort (resigned) under the Mortgage, and by Grainger S. Greene accepting said appointment, and said instrument was appropriately filed or recorded in various official records in the States of Arkansas, Missouri, Tennessee and Wyoming; and

WHEREAS, by the Twenty-first Supplemental Indenture mentioned below, the Company, among other things, appointed John W. Flaherty as Co-Trustee in succession to Grainger S. Greene (resigned) under the Mortgage, and John W. Flaherty accepted said appointment; and

WHEREAS, by the Thirty-third Supplemental Indenture mentioned below, the Company, among other things, appointed Marvin A. Mueller as Missouri Co-Trustee under the Mortgage, and Marvin A. Mueller accepted said appointment; and

WHEREAS, by the Thirty-fifth Supplemental Indenture mentioned below, the Company, among other things, appointed The Boatmen's National Bank of St. Louis as Missouri Co-Trustee in succession to Marvin A. Mueller (resigned) under the Mortgage, and The Boatmen's National Bank of St. Louis accepted said appointment; and

WHEREAS, an instrument, dated as of September 1, 1994, was executed by the Company appointing Bankers Trust Company as Trustee, and Stanley Burg as Co-Trustee, in succession to Morgan Guaranty Trust Company of New York (resigned) and John W. Flaherty (resigned), respectively, under the Mortgage and Bankers Trust Company and Stanley Burg accepted said appointments, and said instrument was appropriately filed or recorded in various official records in the States of Arkansas, Missouri, Tennessee and Wyoming; and

WHEREAS, by the Fifty-fifth Supplemental Indenture mentioned below, the Company, among other things, appointed Peter D. Van Cleve as Missouri Co-Trustee in succession to The Boatmen's National Bank of St. Louis (resigned) under the Mortgage, and Peter D. Van Cleve accepted said appointment; and

WHEREAS, by an instrument, dated as of May 31, 2000, the Company appointed BNY Trust Company of Missouri as Missouri Co-Trustee in succession to Peter D. Van Cleve (resigned) under the Mortgage, and BNY Trust Company of Missouri accepted said appointment, and said instrument was appropriately filed or recorded in various official records in the State of Missouri; and

WHEREAS, by an instrument, dated as of April 15, 2002, filed with the Banking Department of the State of New York, Bankers Trust Company, Trustee, effected a corporate name change pursuant to which, effective such date, it is known as Deutsche Bank Trust Company Americas; and

WHEREAS, by an instrument dated November 1, 2004, filed with the Office of the Comptroller of the Currency in Colorado, BNY Trust Company of Missouri merged into BNY Missouri Interim Trust Company, National Association, and by an instrument dated November 1, 2004, filed with the Office of the Comptroller of the Currency in Colorado, BNY Missouri Interim Trust Company, National Association, merged into The Bank of New York Trust Company, National Association; and

WHEREAS, by the Sixty-third Supplemental Indenture mentioned below, the Company, the Corporate Trustee, Stanley Burg as Co-Trustee, and The Bank of New York Trust Company, National Association, as Missouri Co-Trustee, appointed Jeffrey Schroeder to serve as a Missouri Co-Trustee under the Mortgage, and Jeffrey Schroeder accepted such appointment; and

WHEREAS, by an instrument effective as of February 28, 2005, Jeffrey Schroeder resigned as a Missouri Co-Trustee; and

WHEREAS, effective July 1, 2008, The Bank of New York Trust Company, National Association changed its name to The Bank of New York Mellon Trust Company, National Association; and

WHEREAS, by the Mortgage the Company covenanted that it would execute and deliver such supplemental indenture or indentures and such further instruments and do such further acts as might be necessary or proper to carry out more effectually the purposes of the Mortgage and to make subject to the lien of the Mortgage any property thereafter acquired and intended to be subject to the lien thereof; and

WHEREAS, the Company executed and delivered to the Trustees the following supplemental indentures:

Designation	Dated as of
First Supplemental Indenture	July 1, 1947
Second Supplemental Indenture	August 1, 1948
Third Supplemental Indenture	October 1, 1949
Fourth Supplemental Indenture	June 1, 1950
Fifth Supplemental Indenture	October 1, 1951
Sixth Supplemental Indenture	September 1, 1952
Seventh Supplemental Indenture	June 1, 1953
Eighth Supplemental Indenture	August 1, 1954
Ninth Supplemental Indenture	April 1, 1955
Tenth Supplemental Indenture	December 1, 1959
Eleventh Supplemental Indenture	May 1, 1961
Twelfth Supplemental Indenture	February 1, 1963
Thirteenth Supplemental Indenture	April 1, 1965
Fourteenth Supplemental Indenture	March 1, 1966
Fifteenth Supplemental Indenture	March 1, 1967
Sixteenth Supplemental Indenture	April 1, 1968
Seventeenth Supplemental Indenture	June 1, 1968
Eighteenth Supplemental Indenture	December 1, 1969
Nineteenth Supplemental Indenture	August 1, 1970
Twentieth Supplemental Indenture	March 1, 1971
Twenty-first Supplemental Indenture	August 1, 1971
Twenty-second Supplemental Indenture	April 1, 1972
Twenty-third Supplemental Indenture	December 1, 1972
Twenty-fourth Supplemental Indenture	June 1, 1973
Twenty-fifth Supplemental Indenture	December 1, 1973
Twenty-sixth Supplemental Indenture	June 1, 1974
Twenty-seventh Supplemental Indenture	November 1, 1974
Twenty-eighth Supplemental Indenture	July 1, 1975
Twenty-ninth Supplemental Indenture	December 1, 1977
Thirtieth Supplemental Indenture	July 1, 1978
Thirty-first Supplemental Indenture	February 1, 1979
Thirty-second Supplemental Indenture	December 1, 1980
Thirty-third Supplemental Indenture	January 1, 1981
Thirty-fourth Supplemental Indenture	August 1, 1981
Thirty-fifth Supplemental Indenture	February 1, 1982
Thirty-sixth Supplemental Indenture	December 1, 1982
Thirty-seventh Supplemental Indenture	February 1, 1983
Thirty-eighth Supplemental Indenture	December 1, 1984
Thirty-ninth Supplemental Indenture	December 1, 1985
Fortieth Supplemental Indenture	July 1, 1986
Forty-first Supplemental Indenture	July 1, 1989
Forty-second Supplemental Indenture	February 1, 1990
Forty-third Supplemental Indenture	October 1, 1990
Forty-fourth Supplemental Indenture	November 1, 1990
Forty-fifth Supplemental Indenture	January 1, 1991
Forty-sixth Supplemental Indenture	August 1, 1992
Forty-seventh Supplemental Indenture	November 1, 1992
Forty-eighth Supplemental Indenture	June 15, 1993
Forty-ninth Supplemental Indenture	August 1, 1993
Fiftieth Supplemental Indenture	October 1, 1993
Fifty-first Supplemental Indenture	October 1, 1993
Fifty-second Supplemental Indenture	June 15, 1994
Fifty-third Supplemental Indenture	March 1, 1996
Fifty-fourth Supplemental Indenture	March 1, 1997
Fifty-fifth Supplemental Indenture	March 1, 2000
Fifty-sixth Supplemental Indenture	July 1, 2001
Fifty-seventh Supplemental Indenture	March 1, 2002
Fifty-eighth Supplemental Indenture	November 1, 2002
Fifty-ninth Supplemental Indenture	May 1, 2003
Sixtieth Supplemental Indenture	June 1, 2003
Sixty-first Supplemental Indenture	June 15, 2003
Sixty-second Supplemental Indenture	October 1, 2004
Sixty-third Supplemental Indenture	January 1, 2005
Sixty-fourth Supplemental Indenture	March 1, 2005
Sixty-fifth Supplemental Indenture	May 1, 2005
Sixty-sixth Supplemental Indenture	June 1, 2006

which supplemental indentures were appropriately filed or recorded in various official records in the States of Arkansas, Missouri, Tennessee and Wyoming, as applicable; and

WHEREAS, in addition to the property described in the Mortgage, as heretofore supplemented, the Company has acquired certain other property, rights and interests in property; and

WHEREAS, the Company has heretofore issued, in accordance with the provisions of the Mortgage, as supplemented, the following series of First Mortgage Bonds:

Series	Principal Amount Issued	Principal Amount Outstanding
3 1/8% Series due 1974	$30,000,000	None
2 7/8% Series due 1977	11,000,000	None
3 1/8% Series due 1978	7,500,000	None
2 7/8% Series due 1979	8,700,000	None
2 7/8% Series due 1980	6,000,000	None
3 5/8% Series due 1981	8,000,000	None
3 1/2% Series due 1982	15,000,000	None
4 1/4% Series due 1983	18,000,000	None
3 1/4% Series due 1984	7,500,000	None
3 3/8% Series due 1985	18,000,000	None
5 5/8% Series due 1989	15,000,000	None
4 7/8% Series due 1991	12,000,000	None
4 3/8% Series due 1993	15,000,000	None
4 5/8% Series due 1995	25,000,000	None
5 3/4% Series due 1996	25,000,000	None
5 7/8% Series due 1997	30,000,000	None
7 3/8% Series due 1998	15,000,000	None
9 1/4% Series due 1999	25,000,000	None
9 5/8% Series due 2000	25,000,000	None
7 5/8% Series due 2001	30,000,000	None
8 % Series due August 1, 2001	30,000,000	None
7 3/4% Series due 2002	35,000,000	None
7 1/2% Series due December 1, 2002	15,000,000	None
8 % Series due 2003	40,000,000	None
8 1/8% Series due December 1, 2003	40,000,000	None
10 1/2% Series due 2004	40,000,000	None
9 1/4% Series due November 1, 1981	60,000,000	None
10 1/8% Series due July 1, 2005	40,000,000	None
9 1/8% Series due December 1, 2007	75,000,000	None
9 7/8% Series due July 1, 2008	75,000,000	None
10 1/4% Series due February 1, 2009	60,000,000	None
16 1/8% Series due December 1, 1986	70,000,000	None
4 1/2% Series due September 1, 1983	1,202,000	None
5 1/2% Series due January 1, 1988	598,310	None
5 5/8% Series due May 1, 1990	1,400,000	None
6 1/4% Series due December 1, 1996	3,560,000	None
9 3/4% Series due September 1, 2000	4,600,000	None
8 3/4% Series due March 1, 1998	9,800,000	None
17 3/8% Series due August 1, 1988	75,000,000	None
16 1/2% Series due February 1, 1991	80,000,000	None
13 3/8% Series due December 1, 2012	75,000,000	None
13 1/4% Series due February 1, 2013	25,000,000	None
14 1/8% Series due December 1, 2014	100,000,000	None
Pollution Control Series A	128,800,000	None
10 1/4% Series due July 1, 2016	50,000,000	None
9 3/4% Series due July 1, 2019	75,000,000	None
10% Series due February 1, 2020	150,000,000	None
10 3/8% Series due October 1, 2020	175,000,000	None
Solid Waste Disposal Series A	21,066,667	None
Solid Waste Disposal Series B	28,440,000	None
7 1/2% Series due August 1, 2007	100,000,000	None
7.90% Series due November 1, 2002	25,000,000	None
8.70% Series due November 1, 2022	25,000,000	None
Pollution Control Series B	46,875,000	None
6.65% Series due August 1, 2005	115,000,000	None
6 % Series due October 1, 2003	155,000,000	None
7 % Series due October 1, 2023	175,000,000	None
Pollution Control Series C	20,319,000	$20,319,000
Pollution Control Series D	9,586,400	None
8 3/4% Series due March 1, 2026	85,000,000	None
7% Series due March 1, 2002	85,000,000	None
7.72 % Series due March 1, 2003	100,000,000	None
6 1/8 % Series due July 1, 2005	100,000,000	None
6.70% Series due April 1, 2032	100,000,000	100,000,000
6.00% Series due November 1, 2032	100,000,000	100,000,000
5.40% Series due May 1, 2018	150,000,000	150,000,000
5.90% Series due June 1, 2033	100,000,000	100,000,000
5% Series due July 1, 2018	115,000,000	115,000,000
6.38% Series due November 1, 2034	60,000,000	60,000,000
5.66% Series due February 1, 2025	175,000,000	175,000,000
5% Pollution Control Series E	45,000,000	45,000,000
4.50% Series due June 1, 2010	100,000,000	100,000,000
Pollution Control Series F	56,378,000	56,378,000

which bonds are also hereinafter sometimes called bonds of the First through Seventy-third Series, respectively; and

WHEREAS, Section 8 of the Mortgage provides that the form of each series of bonds (other than the First Series) issued thereunder and of the coupons to be attached to coupon bonds of such series shall be established by Resolution of the Board of Directors of the Company and that the form of such series, as established by said Board of Directors, shall specify the descriptive title of the bonds and various other terms thereof, and may also contain such provisions not inconsistent with the provisions of the Mortgage as the Board of Directors may, in its discretion, cause to be inserted therein expressing or referring to the terms and conditions upon which such bonds are to be issued and/or secured under the Mortgage; and

WHEREAS, Section 120 of the Mortgage provides, among other things, that any power, privilege or right expressly or impliedly reserved to or in any way conferred upon the Company by any provision of the Mortgage, whether such power, privilege or right is in any way restricted or is unrestricted, may be in whole or in part waived or surrendered or subjected to any restriction if at the time unrestricted or to additional restriction if already restricted, and the Company may enter into any further covenants, limitations or restrictions for the benefit of any one or more series of bonds issued thereunder, or the Company may cure any ambiguity contained therein or in any supplemental indenture, or may establish the terms and provisions of any series of bonds other than said First Series, by an instrument in writing executed and acknowledged by the Company in such manner as would be necessary to entitle a conveyance of real estate to record in all of the states in which any property at the time subject to the lien of the Mortgage shall be situated; and

WHEREAS, the Company now desires to create a new series of bonds, hereinafter referred to as bonds of the Seventy-fourth Series, unless the context otherwise requires, and (pursuant to the provisions of Section 120 of the Mortgage) to add to its covenants and agreements contained in the Mortgage, as heretofore supplemented, certain other covenants and agreements to be observed by it and to alter and amend in certain respects the covenants and provisions contained in the Mortgage, as heretofore supplemented; and

WHEREAS, the execution and delivery by the Company of this Sixty-seventh Supplemental Indenture, and the terms of the bonds of the Seventy-fourth Series, have been duly authorized by the Board of Directors of the Company by appropriate Resolutions of said Board of Directors.

NOW, THEREFORE, THIS INDENTURE WITNESSETH:

That the Company, in consideration of the premises and of One Dollar to it duly paid by the Trustees at or before the ensealing and delivery of these presents, the receipt whereof is hereby acknowledged, and in further evidence of assurance of the estate, title and rights of the Trustees and in order further to secure the payment of both the principal of and interest and premium, if any, on the bonds from time to time issued under the Mortgage, according to their tenor and effect and the performance of all the provisions of the Mortgage (including any instruments supplemental thereto and any modifications made as in the Mortgage provided) and of said bonds, hereby grants, bargains, sells, releases, conveys, assigns, transfers, mortgages, hypothecates, affects, pledges, sets over and confirms (subject, however, to Excepted Encumbrances as defined in Section 6 of the Mortgage) unto The Bank of New York Mellon Trust Company, National Association (as to property, real or personal, situated or being in Missouri) and Stanley Burg (but, as to property, real or personal, situated or being in Missouri, only to the extent of his legal capacity to hold the same for the purposes hereof) and (to the extent of its legal capacity to hold the same for the purposes hereof) to Deutsche Bank Trust Company Americas, as Trustees under the Mortgage, and to their successor or successors in said trust, and to them and their successors and assigns forever, all property, real, personal or mixed, of any kind or nature acquired by the Company after the date of the execution and delivery of the Mortgage (except any herein or in the Mortgage, as heretofore supplemented, expressly excepted), now owned or, subject to the provisions of Section 87 of the Mortgage, hereafter acquired by the Company (by purchase, consolidation, merger, donation, construction, erection or in any other way) and wheresoever situated, including (without in anywise limiting or impairing by the enumeration of the same the scope and intent of the fore going or of any general description contained in this Sixty-seventh Supplemental Indenture) all lands, power sites, flowage rights, water rights, water locations, water appropriations, ditches, flumes, reservoirs, reservoir sites, canals, raceways, dams, dam sites, aqueducts, and all other rights or means for appropriating, conveying, storing and supplying water; all rights of way and roads; all plants for the generation of electricity by steam, water and/or other power; all power houses, gas plants, street lighting systems, standards and other equipment incidental thereto; all street and interurban railway and transportation lines and systems, terminal systems and facilities; all bridges, culverts, tracks, railways, sidings, spurs, wyes, roadbeds, trestles and viaducts; all overground and underground trolleys and feeder wires; all telephone, radio and television systems, air-conditioning systems and equipment incidental thereto, water works, water systems, steam heat and hot water plants, substations, lines , service and supply systems, ice or refrigeration plants and equipment, offices, buildings and other structures and the equipment thereof, all machinery, engines, boilers, dynamos, electric, gas and other machines, regulators, meters, transformers, generators, motors, electrical, gas and mechanical appliances, conduits, cables, water, steam heat, gas or other pipes, gas mains and pipes, service pipes, fittings, valves and connections, pole and transmission lines, wires, cables, tools, implements, apparatus, furniture and chattels; all municipal and other franchises, consents or permits; all lines for the transmission and distribution of electric current, gas, steam heat or water for any purpose including towers, poles, wires, cables, pipes, conduits, ducts and all apparatus for use in connection therewith; all real estate, lands, easements, servitudes, licenses, permits, franchises, privileges, rights of way and other rights in or relating to real estate or the occupancy of the same and (except as herein or in the Mortgage, as heretofore supplemented, expressly excepted) all the right, title and interest of the Company in and to all other property of any kind or nature appertaining to and/or used and/or occupied and/or enjoyed in connection with any property hereinbefore or in the Mortgage, as heretofore supplemented, described.

TOGETHER WITH all and singular the tenements, hereditaments, prescriptions, servitudes and appurtenances belonging or in anywise appertaining to the aforesaid property or any part thereof, with the reversion and reversions, remainder and remainders and (subject to the provisions of Section 57 of the Mortgage) the tolls, rents, revenues, issues, earnings, income, product and profits thereof and all the estate, right, title and interest and claim whatsoever, at law as well as in equity, which the Company now has or may hereafter acquire in and to the aforesaid property and franchises and every part and parcel thereof.

IT IS HEREBY AGREED by the Company that, subject to the provisions of Section 87 of the Mortgage, all the property, rights and franchises acquired by the Company (by purchase, consolidation, merger, donation, construction, erection or in any other way) after the date hereof, except any herein or in the Mortgage, as heretofore supplemented, expressly excepted, shall be and are as fully granted and conveyed hereby and by the Mortgage and as fully embraced within the lien hereof and the lien of the Mortgage, as heretofore supplemented, as if such property, rights and franchises were now owned by the Company and were specifically described herein or in the Mortgage and conveyed hereby or thereby.

PROVIDED THAT the following are not and are not intended to be now or hereafter granted, bargained, sold, released, conveyed, assigned, transferred, mortgaged, hypothecated, affected, pledged, set over or confirmed hereunder and are hereby expressly excepted from the lien and operation of this Sixty-seventh Supplemental Indenture and from the lien and operation of the Mortgage, as heretofore supplemented, viz: (1) cash, shares of stock, bonds, notes and other obligations and other securities not hereafter specifically pledged, paid, deposited, delivered or held under the Mortgage or covenanted so to be; (2) merchandise, equipment, materials or supplies held for the purpose of sale in the usual course of business or for the purpose of repairing or replacing (in whole or in part) any street cars, rolling stock, trolley coaches, motor coaches, buses, automobiles or other vehicles or aircraft, and fuel, oil and similar materials and supplies consumable in the operation of any properties of the Company; street cars, rolling stock, trolley coaches, motor coaches, buses, automobiles and other vehicles and all aircraft; (3) bills, notes and accounts receivable, judgments, demands and choses in action, and all contracts, leases and operating agreements not specifically pledged under the Mortgage, as heretofore supplemented, or covenanted so to be; the Company's contractual rights or other interest in or with respect to tires not owned by the Company; (4) the last day of the term of any lease or leasehold which may hereafter become subject to the lien of the Mortgage; (5) electric energy, gas, ice, and other materials or products generated, manufactured, produced or purchased by the Company for sale, distribution or use in the ordinary course of its business; all timber, minerals, mineral rights and royalties; (6) the Company's franchise to be a corporation; (7) the properties heretofore sold or in the process of being sold by the Company and heretofore released from the Mortgage and Deed of Trust date d as of October 1, 1926 from Arkansas Power & Light Company to Guaranty Trust Company of New York, trustee, and specifically described in a release instrument executed by Guaranty Trust Company of New York, as trustee, dated October 13, 1938, which release has heretofore been delivered by the said trustee to the Company and recorded by the Company in the office of the Recorder for Garland County, Arkansas, in Record Book 227, Page 1, all of said properties being located in Garland County, Arkansas; and (8) any property heretofore released pursuant to any provisions of the Mortgage and not heretofore disposed of by the Company; provided, however, that the property and rights expressly excepted from the lien and operation of the Mortgage, as heretofore supplemented, and this Sixty-seventh Supplemental Indenture in the above subdivisions (2) and (3) shall (to the extent permitted by law) cease to be so excepted in the event and as of the date that any or all of the Trustees or a receiver or trustee shall en ter upon and take possession of the Mortgaged and Pledged Property in the manner provided in Article XIII of the Mortgage by reason of the occurrence of a Default as defined in Section 65 thereof.

TO HAVE AND TO HOLD all such properties, real, personal and mixed, granted, bargained, sold, released, conveyed, assigned, transferred, mortgaged, hypothecated, affected, pledged, set over or confirmed by the Company as aforesaid, or intended so to be, unto The Bank of New York Mellon Trust Company, National Association (as to property, real or personal, situated or being in Missouri), and unto Stanley Burg (but, as to property, real or personal, situated or being in Missouri, only to the extent of his legal capacity to hold the same for the purposes hereof) and (to the extent of its legal capacity to hold the same for the purposes hereof) unto Deutsche Bank Trust Company Americas, as Trustees, and their successors and assigns forever.

IN TRUST NEVERTHELESS, for the same purposes and upon the same terms, trusts and conditions and subject to and with the same provisos and covenants as are set forth in the Mortgage, as heretofore supplemented, this Sixty-seventh Supplemental Indenture being supplemental to the Mortgage.

AND IT IS HEREBY COVENANTED by the Company that all the terms, conditions, provisos, covenants and provisions contained in the Mortgage, as heretofore supplemented, shall affect and apply to the property hereinbefore described and conveyed and to the estate, rights, obligations and duties of the Company and Trustees and the beneficiaries of the trust with respect to said property, and to the Trustees and their successors in the trust in the same manner and with the same effect as if said property had been owned by the Company at the time of the execution of the Mortgage, and had been specifically and at length described in and conveyed to said Trustees, by the Mortgage as a part of the property therein stated to be conveyed.

The Company further covenants and agrees to and with the Trustees and their successors in said trust under the Mortgage, as follows:

1. 
   
   SEVENTY-FOURTH SERIES OF BONDS

   1. There shall be a series of bonds designated "5.40% Series due August 1, 2013" (herein sometimes called the "Seventy-fourth Series"), each of which shall also bear the descriptive title "First Mortgage Bond", and the form thereof, which shall be established by Resolution of the Board of Directors of the Company, shall contain suitable provisions with respect to the matters hereinafter in this Section specified. Bonds of the Seventy-fourth Series (which shall be initially issued in the aggregate principal amount of $300,000,000) shall mature on August 1, 2013, shall be issued as fully registered bonds in the denomination of One Thousand Dollars and such other denominations as the officers of the Company shall determine to issue (such determination to be evidenced by the execution and delivery thereof), shall bear interest at the rate of 5.40% per annum, the first interest payment to be made on February 1, 2009, for the period from July 17, 2008 to February 1, 2009 with subseq uent interest payments payable semi-annually on February 1 and August 1 of each year (each an "Interest Payment Date"), shall be dated as in Section 10 of the Mortgage provided, and the principal of, and to the extent permitted by the Mortgage, interest on any overdue principal of, each said bond shall be payable at the office or agency of the Company in the Borough of Manhattan, The City of New York, in such coin or currency of the United States of America as at the time of payment is legal tender for public and private debts.

   Interest on the bonds of the Seventy-fourth Series will be computed on the basis of a 360-day year of twelve 30-day months. In any case where any Interest Payment Date, redemption date or maturity of any bond of the Seventy-fourth Series shall not be a Business Day, then payment of interest or principal need not be made on such date, but may be made on the next succeeding Business Day, with the same force and effect, and in the same amount, as if made on the corresponding Interest Payment Date or redemption date, or at maturity, as the case may be, and, if such payment is made or duly provided for on such Business Day, no interest shall accrue on the amount so payable for the period from and after such Interest Payment Date, redemption date or maturity, as the case may be, to such Business Day. "Business Day" means any day, other than a Saturday or a Sunday, or a day on which banking institutions in The City of New York are authorized or required by law or executive order to rem ain closed or a day on which the corporate trust office of the Corporate Trustee (hereinafter defined) is closed for business.

   So long as all of the bonds of the Seventy-fourth Series are held by The Depository Trust Company or its nominee, or a successor thereof, the record date for the payment of interest on the bonds of the Seventy-fourth Series shall be the Business Day immediately preceding the corresponding Interest Payment Date; provided, however, that the record date for the payment of interest which is paid after such Interest Payment Date, shall be the Business Day immediately preceding the date on which such interest is paid. Interest on the bonds of the Seventy-fourth Series shall be paid to the Person in whose name such bonds of the Seventy-fourth Series are registered at the close of business on the record date for the corresponding Interest Payment Date.

   (I) Form of Bonds of the Seventy-fourth Series.

   The Bonds of the Seventy-fourth Series, and the Corporate Trustee's authentication certificate to be executed on the Bonds of the Seventy-fourth Series, shall be in substantially the following forms, respectively:

   [FORM OF FACE OF BOND OF THE SEVENTY-FOURTH SERIES]

   [depository legend]

   Unless this Certificate is presented by an authorized representative of The Depository Trust Company, a New York corporation ("DTC"), to the Company or its agent for registration of transfer, exchange, or payment, and any certificate issued is registered in the name of Cede & Co. or in such other name as is requested by an authorized representative of DTC (and any payment is made to Cede & Co. or to such other entity as is requested by an authorized representative of DTC), ANY TRANSFER, PLEDGE, OR OTHER USE HEREOF FOR VALUE OR OTHERWISE BY OR TO ANY PERSON IS WRONGFUL inasmuch as the registered owner hereof, Cede & Co., has an interest herein.

   (TEMPORARY REGISTERED BOND)

   No. TR-
   $                                                                                                                                                                     CUSIP 29364D AN 0

   ENTERGY ARKANSAS, INC.
   FIRST MORTGAGE BOND, 5.40% SERIES
   DUE AUGUST 1, 2013

   ENTERGY ARKANSAS, INC., a corporation of the State of Arkansas (hereinafter called the Company), for value received, hereby promises to pay to or registered assigns, on August 1, 2013 at the office or agency of the Company in the Borough of Manhattan, The City of New York,

   DOLLARS

   in such coin or currency of the United States of America as at the time of payment is legal tender for public and private debts, and to pay to the registered owner hereof interest thereon from July 17, 2008, if the date of this bond is prior to February 1, 2009 or if the date of this bond is on or after February 1, 2009, from the February 1 or August 1 next preceding the date of this bond to which interest has been paid (unless the date hereof is an interest payment date to which interest has been paid, in which case from the date hereof), at the rate of 5.40% per annum in like coin or currency at said office or agency on February 1 and August 1 of each year, commencing February 1, 2009, until the principal of this bond shall have become due and payable, and to pay interest on any overdue principal and (to the extent that payment of such interest is enforceable under the applicable law) on any overdue installment of interest at the rate of 6% per annum. So long as this bond is held by The Depository Trust Company or its nominee, or a successor thereof, the record date for the payment of interest hereon shall be the Business Day (as defined in the Sixty-seventh Supplemental Indenture referred to below) immediately preceding the date on which interest is due; provided, however, that the record date for the payment of interest which is paid after the date on which such interest is due, shall be the Business Day immediately preceding the date on which such interest is paid. Interest hereon shall be paid to the Person in whose name this bond is registered at the close of business on the record date for the payment of such interest. If any interest payment date for this bond falls on a day that is not a Business Day, the payment of interest will be made on the next succeeding Business Day, and no interest on such payment shall accrue for the period from and after such interest payment date. If the maturity date or any redemption date of this bond falls on a day that is not a Business Day, the p ayment of principal and interest (to the extent payable with respect to the principal being redeemed if on a redemption date) will be made on the next succeeding Business Day, and no interest on such payment shall accrue for the period from and after the maturity date or such redemption date.

   This bond is a temporary bond and is one of an issue of bonds of the Company issuable in series and is one of a series known as its First Mortgage Bonds, 5.40% Series due August 1, 2013, all bonds of all series issued and to be issued under and equally secured (except insofar as any sinking or other fund, established in accordance with the provisions of the Mortgage hereinafter mentioned, may afford additional security for the bonds of any particular series) by a Mortgage and Deed of Trust (herein, together with any indenture supplemental thereto, including the Sixty-seventh Supplemental Indenture dated as of July 1, 2008, called the Mortgage), dated as of October 1, 1944, executed by the Company to Guaranty Trust Company of New York (Deutsche Bank Trust Company Americas, successor) (herein sometimes called the "Corporate Trustee") and Henry A. Theis (Stanley Burg, successor) and, as to property, real or personal, situated or being in Missouri, Marvin A. Mueller (The Bank of New York Mellon Trust Company, National Association, successor), as Trustees. Reference is made to the Mortgage for a description of the property mortgaged and pledged, the nature and extent of the security, the rights of the holders of the bonds and of the Trustees in respect thereof, the duties and immunities of the Trustees and the terms and conditions upon which the bonds are and are to be secured and the circumstances under which additional bonds may be issued. With the consent of the Company and to the extent permitted by and as provided in the Mortgage, the rights and obligations of the Company and/or the rights of the holders of the bonds and/or coupons and/or the terms and provisions of the Mortgage may be modified or altered by such affirmative vote or votes of the holders of bonds then outstanding as are specified in the Mortgage.

   The principal hereof may be declared or may become due prior to the maturity date hereinbefore named on the conditions, in the manner and at the time set forth in the Mortgage, upon the occurrence of a default as in the Mortgage provided.

   In the manner prescribed in the Mortgage, this bond is transferable by the registered owner hereof in person, or by his duly authorized attorney, at the office or agency of the Company in the Borough of Manhattan, The City of New York, upon surrender and cancellation of this bond, together with a written instrument of transfer duly executed by the registered owner or by his duly authorized attorney, and thereupon a new fully registered temporary or definitive bond of the same series for a like principal amount will be issued to the transferee in exchange herefor as provided in the Mortgage. The Company and the Trustees may deem and treat the person in whose name this bond is registered as the absolute owner hereof for the purpose of receiving payment and for all other purposes and neither the Company nor the Trustees shall be affected by any notice to the contrary.

   In the manner prescribed in the Mortgage, any bonds of this series, upon surrender thereof for cancellation at the office or agency of the Company in the Borough of Manhattan, The City of New York, are exchangeable for a like aggregate principal amount of bonds of the same series of other authorized denominations.

   In the manner prescribed in the Mortgage, this temporary bond is exchangeable at the office or agency of the Company in the Borough of Manhattan, The City of New York, without charge, for a definitive bond or bonds of the same series of a like aggregate principal amount when such definitive bonds are prepared and ready for delivery.

   As provided in the Mortgage, the Company shall not be required to make transfers or exchanges of bonds of any series for a period of ten days next preceding any interest payment date for bonds of said series, or next preceding any designation of bonds of said series to be redeemed, and the Company shall not be required to make transfers or exchanges of any bonds designated in whole or in part for redemption.

   The bonds of this series are subject to redemption as provided in the Sixty-seventh Supplemental Indenture.

   No recourse shall be had for the payment of the principal of or interest on this bond against any incorporator or any past, present or future subscriber to the capital stock, stockholder, officer or director of the Company or of any predecessor or successor corporation, as such, either directly or through the Company or any predecessor or successor corporation, under any rule of law, statute or constitution or by the enforcement of any assessment or otherwise, all such liability of incorporators, subscribers, stockholders, officers and directors being released by the holder or owner hereof by the acceptance of this bond and being likewise waived and released by the terms of the Mortgage.

   This bond shall be construed in accordance with and governed by the laws of the State of New York.

   This bond shall not become obligatory until Deutsche Bank Trust Company Americas, the Corporate Trustee under the Mortgage, or its successor thereunder, shall have signed the form of authentication certificate endorsed hereon.

   IN WITNESS WHEREOF, ENTERGY ARKANSAS, INC. has caused this bond to be signed in its corporate name by its President or one of its Vice Presidents by his/her signature or a facsimile thereof, and its corporate seal to be impressed or imprinted hereon and attested by its Secretary or one of its Assistant Secretaries, by his/her signature or a facsimile thereof, on .

   ENTERGY ARKANSAS, INC.

   By_____________________________

   Attest:

   ___________________________

   CORPORATE TRUSTEE'S AUTHENTICATION CERTIFICATE

   This bond is one of the bonds, of the series herein designated, described or provided for in the within-mentioned Mortgage.

   DEUTSCHE BANK TRUST COMPANY AMERICAS,
   as Corporate Trustee

   By ___________________________
   Authorized Officer

   (II) The bonds of the Seventy-fourth Series shall be redeemable at the option of the Company, in whole or in part, on not less than 30 days nor more than 60 days notice prior to the date fixed for redemption, at any time prior to maturity of the bonds of the Seventy-fourth Series, at a redemption price equal to the greater of (a) 100% of the principal amount of such bonds of the Seventy-fourth Series being redeemed and (b) as determined by the Independent Investment Banker, the sum of the present values of the remaining scheduled payments of principal and interest on such bonds of the Seventy-fourth Series being redeemed (excluding the portion of any such interest accrued to such redemption date), discounted (for purposes of determining such present values) to such redemption date on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Adjusted Treasury Rate plus 0.35%, plus, in each case, accrued and unpaid interest thereon to such redemption date .

   As used herein, the following defined terms shall have the respective meanings specified unless the context clearly requires otherwise:

   The term "Adjusted Treasury Rate" shall mean, with respect to any redemption date:

   (1) the yield, under the heading which represents the average for the immediately preceding week, appearing in the most recently published statistical release designated "H.15(519)" or any successor publication which is published weekly by the Board of Governors of the Federal Reserve System and which establishes yields on actively traded United States Treasury securities adjusted to constant maturity under the caption "Treasury Constant Maturities," for the maturity corresponding to the Comparable Treasury Issue (if no maturity is within three months before or after August 1, 2013, yields for the two published maturities most closely corresponding to the Comparable Treasury Issue shall be determined and the Adjusted Treasury Rate shall be interpolated or extrapolated from such yields on a straight line basis, rounding to the nearest month); or

   (2) if such release (or any successor release) is not published during the week preceding the calculation date for the Adjusted Treasury Rate or does not contain such yields, the rate per annum equal to the semi-annual equivalent yield to maturity of the Comparable Treasury Issue, calculated using a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such redemption date.

   The Adjusted Treasury Rate shall be calculated on the third Business Day preceding the redemption date.

   The term "Comparable Treasury Issue" shall mean the United States Treasury security selected by the Independent Investment Banker as having a maturity comparable to August 1, 2013 that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to August 1, 2013.

   The term "Comparable Treasury Price" shall mean, with respect to any redemption date, (i) the average of five Reference Treasury Dealer Quotations for such redemption date after excluding the highest and lowest such Reference Treasury Dealer Quotations or (ii) if the Independent Investment Banker obtains fewer than five such Reference Treasury Dealer Quotations, the average of all such Reference Treasury Dealer Quotations.

   The term "Independent Investment Banker" shall mean one of the Reference Treasury Dealers that the Company appoints to act as the Independent Investment Banker from time to time, or, if any of such firms is unwilling or unable to select the Comparable Treasury Issue, an independent investment banking institution of national standing appointed by the Company.

   The term "Reference Treasury Dealer" shall mean (i) Barclays Capital Inc., BNY Mellon Capital Markets, LLC, J.P. Morgan Securities Inc. and their respective successors; provided, however, that if any of the foregoing shall cease to be a primary U.S. Government securities dealer in New York City (a "Primary Treasury Dealer"), the Company shall substitute therefor another Primary Treasury Dealer, and (ii) any other Primary Treasury Dealer selected by the Independent Investment Banker after consultation with the Company.

   The term "Reference Treasury Dealer Quotations" shall mean, with respect to each Reference Treasury Dealer and any redemption date, the average, as determined by the Independent Investment Banker, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to the Independent Investment Banker at 5:00 p.m. on the third Business Day preceding such redemption date.

   (III) At the option of the registered owner, any bonds of the Seventy-fourth Series, upon surrender thereof for cancellation at the office or agency of the Company in the Borough of Manhattan, The City of New York, shall be exchangeable for a like aggregate principal amount of bonds of the same series of other authorized denominations.

   Bonds of the Seventy-fourth Series shall be transferable, upon the surrender thereof for cancellation, together with a written instrument of transfer in form approved by the registrar duly executed by the registered owner or by his duly authorized attorney, at the office or agency of the Company in the Borough of Manhattan, The City of New York.

   Upon any exchange or transfer of bonds of the Seventy-fourth Series, the Company may make a charge therefor sufficient to reimburse it for any tax or taxes or other governmental charge, as provided in Section 12 of the Mortgage, but the Company hereby waives any right to make a charge in addition thereto for any exchange or transfer of bonds of said Series.

   Upon the delivery of this Sixty-seventh Supplemental Indenture and upon compliance with the applicable provisions of the Mortgage, as heretofore supplemented, there shall be an initial issue of bonds of the Seventy-fourth Series for the aggregate principal amount of $300,000,000.

2. 
   
   MISCELLANEOUS PROVISIONS

   1. The holders of the bonds of the Seventy-fourth Series shall be deemed to have consented and agreed that the Company may, but shall not be obligated to, fix a record date for the purpose of determining the holders of the bonds of the Seventy-fourth Series entitled to consent to any amendment or supplement to the Mortgage or the waiver of any provision thereof or any act to be performed thereunder. If a record date is fixed, those persons who were holders at such record date (or their duly designated proxies), and only those persons, shall be entitled to consent to such amendment, supplement or waiver or to revoke any consent previously given, whether or not such persons continue to be holders after such record date. No such consent shall be valid or effective for more than 90 days after such record date.
   2. Subject to the amendments provided for in this Sixty-seventh Supplemental Indenture, the terms defined in the Mortgage and the First through Sixty-sixth Supplemental Indentures shall, for all purposes of this Sixty-seventh Supplemental Indenture, have the meanings specified in the Mortgage and the First through Sixty-sixth Supplemental Indentures.
   3. The Trustees hereby accept the trusts herein declared, provided, created or supplemented and agree to perform the same upon the terms and conditions herein and in the Mortgage and in the First through Sixty-sixth Supplemental Indentures set forth and upon the following terms and conditions:

      The Trustees shall not be responsible in any manner whatsoever for or in respect of the validity or sufficiency of this Sixty-seventh Supplemental Indenture or for or in respect of the recitals contained herein, all of which recitals are made by the Company solely. In general each and every term and condition contained in Article XVII of the Mortgage, as heretofore amended, shall apply to and form part of this Sixty-seventh Supplemental Indenture with the same force and effect as if the same were herein set forth in full with such omissions, variations and insertions, if any, as may be appropriate to make the same conform to the provisions of this Sixty-seventh Supplemental Indenture.

   4. Whenever in this Sixty-seventh Supplemental Indenture any of the parties hereto is named or referred to, this shall, subject to the provisions of Articles XVI and XVII of the Mortgage, as heretofore amended, be deemed to include the successors and assigns of such party, and all the covenants and agreements in this Sixty-seventh Supplemental Indenture contained by or on behalf of the Company, or by or on behalf of the Trustees, or any of them, shall, subject as aforesaid, bind and inure to the respective benefits of the respective successors and assigns of such parties, whether so expressed or not.
   5. Nothing in this Sixty-seventh Supplemental Indenture, expressed or implied, is intended, or shall be construed, to confer upon, or give to, any person, firm or corporation, other than the parties hereto and the holders of the bonds and coupons Outstanding under the Mortgage, any right, remedy or claim under or by reason of this Sixty-seventh Supplemental Indenture or any covenant, condition, stipulation, promise or agreement hereof, and all the covenants, conditions, stipulations, promises or agreements in this Sixty-seventh Supplemental Indenture contained by or on behalf of the Company shall be for the sole and exclusive benefit of the parties hereto, and of the holders of the bonds and of the coupons Outstanding under the Mortgage.
   6. This Sixty-seventh Supplemental Indenture shall be executed in several counterparts, each of which shall be an original and all of which shall constitute but one and the same instrument.
   7. This Sixty-seventh Supplemental Indenture shall be construed in accordance with and governed by the laws of the State of New York.

IN WITNESS WHEREOF, ENTERGY ARKANSAS, INC. has caused its corporate name to be hereunto affixed, and this instrument to be signed and sealed by its President or one of its Vice Presidents, and its corporate seal to be attested by its Secretary or one of its Assistant Secretaries for and in its behalf, and DEUTSCHE BANK TRUST COMPANY AMERICAS has caused its corporate name to be hereunto affixed, and this instrument to be signed and sealed by, one of its Vice Presidents or one of its Assistant Vice Presidents, and its corporate seal to be attested by one of its Associates for and in its behalf, and STANLEY BURG has hereunto set his hand and affixed his seal, and THE BANK OF NEW YORK MELLON TRUST COMPANY, NATIONAL ASSOCIATION has caused its name to be hereunto affixed, and this instrument to be signed and sealed by one of its Vice Presidents or one of its Assistant Vice Presidents, and its seal to be attested by one of its Assistant Secretaries or one of its Assistant Treasurers or one of its Assistant Vice Presidents for and in its behalf, as of the day and year first above written.

ENTERGY ARKANSAS, INC.

By:     /s/ Steven C. McNeal                        
Steven C. McNeal
Vice President and Treasurer

Attest:

/s/ Dawn A. Abuso                         
Dawn A. Abuso
Assistant Secretary

Executed, sealed and delivered by
ENTERGY ARKANSAS, INC.
in the presence of:

/s/ Christina M. Edwards                
Christina M. Edwards

s/ Sylvia S. Higgins                         
Sylvia S. Higgins

DEUTSCHE BANK TRUST COMPANY AMERICAS,
As Corporate Trustee

By:     /s/ Carol Ng                                    
Carol Ng
Vice President

Attest:

/s/ Jennifer Davis                      
Jennifer Davis
Associate

STANLEY BURG,
As Co-Trustee

/s/ Stanley Burg                                    [L.S.]

Executed, sealed and delivered by
DEUTSCHE BANK TRUST COMPANY AMERICAS and STANLEY BURG
in the presence of:

/s/ Alexander Buslayev               
Alexander Buslayev

/s/ Yana Kislenko                        
Yana Kislenko

THE BANK OF NEW YORK MELLON TRUST COMPANY, NATIONAL ASSOCIATION,
As Co-Trustee as to property, real or personal, situated or being in Missouri

By:      /s/ Geraldine Creswell                     
Geraldine Creswell
Assistant Treasurer

Attest:

/s/ Christie Leppert                                
Christie Leppert

Assistant Vice President

Executed, sealed and delivered by
THE BANK OF NEW YORK MELLON TRUST COMPANY,
NATIONAL ASSOCIATION
in the presence of:

/s/ Kristin Haskins                                
Kristin Haskins

/s/ Scott Williams                                 
Scott Williams

STATE OF LOUISIANA )
                                         ) SS.:
PARISH OF ORLEANS )

On this 15th day of July, 2008, before me, Jennifer Favalora, a Notary Public duly commissioned, qualified and acting within and for said Parish and State, appeared in person the within named Steven C. McNeal and Dawn A. Abuso, to me personally well known, who stated that they were the Vice President and Treasurer and Assistant Secretary, respectively, of ENTERGY ARKANSAS, INC., a corporation, and were duly authorized in their respective capacities to execute the foregoing instrument for and in the name and behalf of said corporation, and further stated and acknowledged that they had so signed, executed and delivered said foregoing instrument for the consideration, uses and purposes therein mentioned and set forth.

On the 15th day of July, 2008, before me personally came Steven C. McNeal, to me known, who, being by me duly sworn, did depose and say that he resides at 7903 Winner's Circle, Mandeville, Louisiana 70448; that he is the Vice President and Treasurer of ENTERGY ARKANSAS, INC., one of the corporations described in and which executed the above instrument; that he knows the seal of said corporation; that the seal affixed to said instrument is such corporate seal; that it was so affixed by order of the Board of Directors of said corporation, and that he signed his name thereto by like order.

On the 15th day of July, 2008, before me appeared Dawn A. Abuso, to me personally known, who, being by me duly sworn, did say that she is the Assistant Secretary of ENTERGY ARKANSAS, INC., and that the seal affixed to the foregoing instrument is the corporate seal of said corporation, and that said instrument was signed and sealed in behalf of said corporation by authority of its Board of Directors, and she acknowledged said instrument to be the free act and deed of said corporation.

IN TESTIMONY WHEREOF, I have hereunto set my hand and affixed my official seal at my office in said Parish and State the day and year last above written.

/s/ Jennifer Favalora                                      
Jennifer Favalora
Notary Public No. 57639
Parish of Orleans, State of Louisiana
My Commission is issued for Life.

STATE OF NEW YORK      )
                                              ) SS.:
COUNTY OF NEW YORK )

On this 14^th day of July, 2008, before me, Annie Jaghatspanyan, a Notary Public duly commissioned, qualified and acting within and for said County and State, appeared Carol Ng and Jennifer Davis, to me personally well known, who stated that they were a Vice President and an Associate, respectively, of DEUTSCHE BANK TRUST COMPANY AMERICAS, a corporation, and were duly authorized in their respective capacities to execute the foregoing instrument for and in the name and behalf of said corporation; and further stated and acknowledged that they had so signed, executed and delivered said foregoing instrument for the consideration, uses and purposes therein mentioned and set forth.

On the 14^th day of July, 2008, before me personally came Carol Ng, to me known, who, being by me duly sworn, did depose and say that he resides at 60 Wall Street, New York, NY 10005; that she is a Vice President of DEUTSCHE BANK TRUST COMPANY AMERICAS, one of the corporations described in and which executed the above instrument; that she knows the seal of said corporation; that the seal affixed to said instrument is such corporate seal; that it was so affixed by authority of the Board of Directors of said corporation, and that she signed her name thereto by like authority.

On the 14^th day of July, 2008, before me appeared Jennifer Davis, to me personally known, who, being by me duly sworn, did say that she is an Associate of DEUTSCHE BANK TRUST COMPANY AMERICAS, and that the seal affixed to the foregoing instrument is the corporate seal of said corporation, and that said instrument was signed and sealed in behalf of said corporation by authority of its Board of Directors, and [he/she] acknowledged said instrument to be the free act and deed of said corporation.

IN TESTIMONY WHEREOF, I have hereunto set my hand and affixed my official seal at my office in said County and State the day and year last above written.

/s/ Annie Jaghatspanyan                               
Annie Jaghatspanyan
Notary Public, State of New York
No 01JA6062022
Qualified in New York County
Commission Expires September 23, 2009

STATE OF NEW YORK      )
                                              ) SS.:
COUNTY OF NEW YORK )

On this 11^th day of July, 2008, before me, Oneaka Hendricks, the undersigned, personally appeared, STANLEY BURG, known to me to be the person whose name is subscribed to the within instrument, and acknowledged that he executed the same for the purposes therein contained.

On the 11^th day of July, 2008, before me personally appeared STANLEY BURG, to me known to be the person described in and who executed the foregoing instrument, and acknowledged that he executed the same as his free act and deed.

IN WITNESS WHEREOF, I hereunto set my hand and official seal.

/s/ Oneaka Hendricks                                  
Oneaka Hendricks
Notary Public, State of New York
Registration #01HE6063947
Qualified in Kings County
My Commission Expires Sept. 10, 2009

STATE OF FLORIDA  )
                                      ) SS.:
COUNTY OF DUVAL )

On this 17^th day of July, 2008, before me, Lillie C. Mariano, a Notary Public duly commissioned, qualified and acting within and for said county and state, appeared Geraldine Creswell and Christie Leppert, to me personally known, who stated that they were a Assistant Treasurer and Assistant Vice President, respectively, of THE BANK OF NEW YORK MELLON TRUST COMPANY, NATIONAL ASSOCIATION, a National Association, and were duly authorized in their respective capacities to execute the foregoing instrument for and in the name and on behalf of said Company; and further stated that they had so signed, executed and delivered the same for the consideration, uses and purposes therein mentioned and set forth.

On the 17^th day of July, 2008, before me personally appeared Kristin Haskins, to me personally known, who, being by me duly sworn, did depose and say that she resides in Florida; that she is a Trust Associate of THE BANK OF NEW YORK MELLON TRUST COMPANY, NATIONAL ASSOCIATION, one of the entities described in and which executed the above instrument; that she knows the seal of said National Association; that the seal affixed to said instrument is such seal; that it was so affixed by authority of its Board of Directors, and that she signed her name thereto by like authority.

On the 17^th day of July, 2008, before me appeared Scott Williams, to me personally known, who, being by me duly sworn, did say that he resides in Florida; that he is a Trust Associate of THE BANK OF NEW YORK MELLON TRUST COMPANY, NATIONAL ASSOCIATION, and that the seal affixed to the foregoing instrument is the seal of said National Association, and that said instrument was signed and sealed on behalf of said National Association by authority of its Board of Directors, and he acknowledged said instrument to be the free act and deed of said entity.

IN TESTIMONY WHEREOF, I have hereunto set my hand and affixed my official seal at my office in said City and State the day and year last above written.

/s/ Lillie C. Mariano                                      
Lillie C. Mariano
Notary Public, State of Florida
Qualified in Duval County
Commission Expires 09-29-08

EX-4

Exhibit 4(c)

FIRST AMENDMENT TO
MORTGAGE, DEED OF TRUST
AND SECURITY AGREEMENT

ENTERGY TEXAS, INC.

THIS FIRST AMENDMENT TO MORTGAGE, DEED OF TRUST AND SECURITY AGREEMENT (this "Amendment") is made to be effective as of the 20th day of March, 2008, by Entergy Texas, Inc., a Texas corporation ("Mortgagor"), Mark G. Otts ("Trustee"), and Entergy Gulf States Louisiana, L.L.C., a Louisiana limited liability company, successor by merger to Entergy Gulf States Louisiana, Inc. (formerly known as Entergy Gulf States, Inc.), a Texas corporation ("Mortgagee").

WITNESSETH:

WHEREAS, Mortgagor executed and delivered to Trustee for the benefit of Mortgagee that certain Mortgage, Deed of Trust and Security Agreement dated effective as of December 31, 2007, recorded on December 31, 2007, as a Utility Security Instrument in the Uniform Commercial Code Section of the Office of the Texas Secretary of State, Initial Filing Number 07-0043737546, Document Number 198021300002 (the "Deed of Trust"); and

WHEREAS, Mortgagor and Entergy Gulf States Louisiana, Inc. entered into that certain Debt Assumption Agreement dated as of December 31, 2007 (the "Assumption Agreement"), under which Mortgagor assumed the obligations of Mortgagee to pay to the applicable trustee of each series of the Outstanding Debt (as defined in the Deed of Trust) the "Assumed Amounts," which were listed, in dollar amounts, on Schedule 1 of the Assumption Agreement and which were likewise listed on Schedule A of the Deed of Trust; and by Instrument of Correction dated March 20, 2008 (the "Instrument of Correction"), Mortgagor and Mortgagee corrected the Assumption Agreement effective as of December 31, 2007, to correct a mutual mistake of the parties and change the dollar amounts of the Assumed Amounts; and

WHEREAS, Mortgagor, Trustee and Mortgagee (collectively the "Parties") wish to modify and amend Schedule A of the Deed of Trust to correct the assumed amounts stated therein to reflect the Assumed Amounts stated in the Assumption Agreement as corrected by the Instrument of Correction and to amend and modify Schedule B of the Deed of Trust to list additional mortgaged property.

NOW THEREFORE, in consideration of the mutual promises contained herein, and for other good and valuable consideration, the receipt and sufficiency of which are acknowledged by the undersigned, the Parties hereby agree as follows:

1. Schedule A is to be deleted and replaced in its entirety with the Amended Schedule A attached hereto as Exhibit A.

2. Schedule B is amended by adding thereto the text setout in Exhibit B attached hereto.

3. Except as amended by this Amendment, all terms, conditions, rights and obligations contained in the Deed of Trust remain in full force and effect.

IN WITNESS WHEREOF, the Parties hereto have caused this Amendment to the Deed of Trust to be executed by their authorized representatives.

[THE REMAINDER OF THIS PAGE IS INTENTIONALLY LEFT BLANK.
THE NEXT PAGE OF THIS DOCUMENT IS PAGE S-1]

MORTGAGOR:

Entergy Texas, Inc.,
a Texas corporation

By: /s/ Steven C. McNeal

Name: Steven C. McNeal

Title: Vice President and Treasurer

STATE OF LOUISIANA

PARISH OF ORLEANS

This instrument was acknowledged before me on the 20th day of March, 2008, by Steven C. McNeal, Vice President and Treasurer of Entergy Texas, Inc., a Texas corporation, on behalf of said corporation.

/s/ Jennifer Favalora
Jennifer Favalora, Notary Public, State of Louisiana
Notary Identification Number 57639
My commission expires at my death.

TRUSTEE:

/s/ Mark G. Otts

Mark G. Otts

STATE OF LOUISIANA

PARISH OF ORLEANS

This instrument was acknowledged before me on the 20th day of March, 2008, by Mark G. Otts, Trustee.

/s/ Jennifer Favalora
Jennifer Favalora, Notary Public, State of Louisiana
Notary Identification Number 57639
My commission expires at my death.

MORTGAGEE:

Entergy Gulf States Louisiana, L.L.C.,
a Louisiana limited liability company

By: /s/ Steven C. McNeal

Name: Steven C. McNeal

Title: Vice President and Treasurer

STATE OF LOUISIANA

PARISH OF ORLEANS

This instrument was acknowledged before me on the 20th day of March, 2008, by Steven C. McNeal, Vice President and Treasurer of Entergy Gulf States Louisiana, L.L.C., a Louisiana limited liability company, on behalf of said limited liability company.

/s/ Jennifer Favalora
Jennifer Favalora, Notary Public, State of Louisiana
Notary Identification Number 57639
My commission expires at my death.

EXHIBIT A

AMENDED SCHEDULE A

OUTSTANDING DEBT

I. Indenture of Mortgage dated September 1, 1926, between Entergy Gulf States, Inc. (successor to Gulf States Utilities Company) and The Bank of New York (successor to The Chase National Bank of the City of New York), as supplemented and modified.

Name of Series	Outstanding Amount (Millions)	Assumed Amount (Millions)
First Mortgage Bonds, 6% Series due December 1, 2012	$ 140	$ 64.114
First Mortgage Bonds, 3.6% Series due June 1, 2008	$ 325	$ 148.837
First Mortgage Bonds, 6.2% Series due July 1, 2033	$ 240	$ 109.911
First Mortgage Bonds, 5.25% Series due August 1, 2015	$ 200	$ 91.592
First Mortgage Bonds, 4 7/8% Series due November 1, 2011	$ 200	$ 91.592
First Mortgage Bonds, Floating Rate Series due December 1, 2009	$ 219.470	$ 100.509
First Mortgage Bonds, 5.60% Series due December 1, 2014	$ 50	$ 22.898
First Mortgage Bonds, 6.18% Series due March 1, 2035	$ 85	$ 38.927
First Mortgage Bonds, 5.70% Series due June 1, 2015	$ 200	$ 91.592
First Mortgage Bonds, 5.12% Series due August 1, 2010	$ 100	$ 45.796
First Mortgage Bonds, Floating Rate Series due December 8, 2008	$ 350	$ 160.286

II. (a) Sublease Agreement between Parish of West Feliciana, State of Louisiana (the "Issuer") and Entergy Gulf States, Inc. (successor to Gulf States Utilities Company), dated as of November 1, 1985.

(b) Indenture of Trust and Pledge, dated as of November 1, 1985, between the Issuer and The Bank of New York (as successor to Irving Trust Company).

Name of Series	Outstanding Amount (Millions)	Assumed Amount (Millions)
Variable Rate Demand Pollution Control Revenue Bonds (Gulf States Utilities Company Project) Series 1985-C	$ 39	$ 22.440

III. (a) Sublease Agreement between Parish of West Feliciana, State of Louisiana (the "Issuer") and Entergy Gulf States, Inc. (successor to Gulf States Utilities Company), dated as of December 1, 1985.

(b) Indenture of Trust and Pledge, dated as of December 1, 1985, between the Issuer and the Bank of New York (as successor to Irving Trust Company).

Name of Series	Outstanding Amount (Millions)	Assumed Amount (Millions)
Variable Rate Demand Pollution Control Revenue Bonds (Gulf States Utilities Company Project) Series 1985-D	$ 28.4	$ 13.005

IV. (a) Sublease Agreement between Parish of West Feliciana, State of Louisiana (the "Issuer") and Entergy Gulf States, Inc. (successor to Gulf States Utilities Company), dated as of April 1, 1986.

(b) Indenture of Trust and Pledge, dated as of April 1, 1986, between the Issuer and The Bank of New York (as successor to Irving Trust Company).

Name of Series	Outstanding Amount (Millions)	Assumed Amount (Millions)
Multiple Rate Demand Pollution Control Revenue Bonds (Gulf States Utilities Company Project) Series 1986	$ 20	$ 9.160

V. (a) Sublease Agreement between the Industrial Development Board of the Parish of Calcasieu, Inc. (the "Issuer") and Entergy Gulf States, Inc. (successor to Gulf States Utilities Company), dated as of December 1, 1974 as supplemented by Third Supplemental Sublease Agreement between the Issuer and the Company, dated as of August 1, 1992.

(b) Indenture of Trust and Pledge, dated as of December 1, 1974, between the Issuer and The Bank of New York (as successor to Hibernia National Bank), as trustee (the "Trustee"), as supplemented by Third Supplemental Indenture of Trust and Pledge dated as of August 1, 1992 between the Issuer and the Trustee.

Name of Series	Outstanding Amount (Millions)	Assumed Amount (Millions)
Pollution Control Revenue Refunding Bonds (Gulf States Utilities Company Project) Series 1992	$ 48.285	$ 22.115

VI. (a) Sublease Agreement between Parish of Pointe Coupee, State of Louisiana (the "Issuer") and Entergy Gulf States, Inc. (successor to Gulf States Utilities Company) (the "Company"), dated as of March 1, 1983, as supplemented by First Sublease Supplemental Agreement dated as of January 1, 1993, between the Issuer and the Company.

(b) Indenture of Trust and Pledge, dated as of March 1, 1983, between the Issuer and Hancock Bank of Louisiana (as successor to American Bank and Trust Company), as trustee (the "Trustee"), as supplemented by First Supplemental Indenture of Trust and Pledge dated as of January 1, 1993 between the Issuer and the Trustee.

Name of Series	Outstanding Amount (Millions)	Assumed Amount (Millions)
Pollution Control Revenue Refunding Bonds (Gulf States Utilities Company Project) Series 1993	$ 17.450	$ 7.990

VII. (a) Refunding Agreement between Parish of Iberville, State of Louisiana (the "Issuer") and Entergy Gulf States, Inc., dated as of May 1, 1998.

(b) Trust Indenture, dated as of May 1, 1998, between the Issuer and Hancock Bank of Louisiana.

Name of Series	Outstanding Amount (Millions)	Assumed Amount (Millions)
Pollution Control Revenue Refunding Bonds (Entergy Gulf States, Inc. Project) Series 1998	$ 21.6	$ 9.890

VIII. (a) Refunding Agreement between the Industrial Development Board of the Parish of Calcasieu, Inc. (the "Issuer") and Entergy Gulf States, Inc., dated as of May 1, 1998.

(b) Trust Indenture, dated as of May 1, 1998, between the Issuer and The Bank of New York.

Name of Series	Outstanding Amount (Millions)	Assumed Amount (Millions)
Pollution Control Revenue Refunding Bonds (Entergy Gulf States, Inc. Project) Series 1999	$ 22.095	$ 10.120

IX. (a) Refunding Agreement between Parish of West Feliciana, State of Louisiana (the "Issuer") and Entergy Gulf States, Inc., dated as of September 1, 1999.

(b) Trust Indenture, dated as of September 1, 1999, between the Issuer and The Bank of New York.

Name of Series	Outstanding Amount (Millions)	Assumed Amount (Millions)
Pollution Control Revenue Refunding Bonds (Entergy Gulf States, Inc. Project) Series 1999-B	$ 40	$ 18.320

EXHIBIT B

ADDITIONAL MORTGAGED PROPERTY

The additional personal property and fixtures located in one or more of the following counties in Texas: Anderson, Angelina, Austin, Bee, Brazoria, Brazos, Brewster, Brooks, Burleson, Cameron, Chambers, Cherokee, Colorado, Dallas, Donley, Falls, Fort Bend, Freestone, Galveston, Gregg, Grimes, Hardin, Harris, Harrison, Houston, Jackson, Jasper, Jefferson, Lee, Leon, Liberty, Limestone, Live Oak, Madison, Marion, McLennan, Midland, Milam, Montgomery, Nacogdoches, Navarro, Newton, Nueces, Orange, Panola, Polk, Robertson, Rusk, Sabine, San Augustine, San Jacinto, Smith, Tarrant, Travis, Trinity, Tyler, Walker, Waller, Washington, and described on the following pages:

[Description of Property follows]

company	state	major_location	asset_location	func_class	utility_account	retirement_unit	ferc_activity_code	month_number	activity_quantity	activity_cost
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Common - SBC - EGSI - 1890	Production Steam	3120 Boiler Plant Equipment	Chiller, Steam Sampling Lines, Comp	Addition	200712	0	(21.28)
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Common - SBC - EGSI - 1890	Production Steam	3110 Structures & Improvements	Non-Unitized	Addition	200712	1	7,245.25
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Common - SBC - EGSI - 1890	Production Steam	3160 Misc Power Plant Equipment	Analyzer, Condensate: Condensate:	Addition	200712	0	(6.17)
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Common - SBC - EGSI - 1890	Production Steam	3160 Misc Power Plant Equipment	Analyzer, Dissolved Oxygen/Hydrogen	Addition	200712	0	(6.17)
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Common - SBC - EGSI - 1890	Production Steam	3160 Misc Power Plant Equipment	Analyzer, Hydrazine: Hydrazine: P	Addition	200712	0	(13.37)
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Common - SBC - EGSI - 1890	Production Steam	3160 Misc Power Plant Equipment	Analyzer, Phosphate: Phosphate: P	Addition	200712	0	(13.37)
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Common - SBC - EGSI - 1890	Production Steam	3160 Misc Power Plant Equipment	Analyzer, Silica: Silica: PS:Anal	Addition	200712	0	(5.38)
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Common - SBC - EGSI - 1890	Production Steam	3160 Misc Power Plant Equipment	Analyzer, Sodium: Sodium: PS:Anal	Addition	200712	0	(13.37)
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Common - SBC - EGSI - 1890	Production Steam	3160 Misc Power Plant Equipment	Conductivity Meter: PS:Conductivit	Addition	200712	0	(5.56)
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Common - SBC - EGSI - 1890	Production Steam	3150 Accessory Electric Equipment	Non-Unitized	Addition	200710	1	1,378.22
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 1 - SB1 - EGSI - 1891	Production Steam	3140 Turbogenerator Units	Valves: Generic Fossil Ite, Valve,	Addition	200712	2	260,967.81
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 1 - SB1 - EGSI - 1891	Production Steam	3120 Boiler Plant Equipment	Chemical Feed Sys., Boiler, Comp, E	Addition	200712	2	272,889.24
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 2 - SB2 - EGSI - 1892	Production Steam	3140 Turbogenerator Units	Hydrogen System, Main Generator Coo	Addition	200712	1	77,646.45
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 2 - SB2 - EGSI - 1892	Production Steam	3140 Turbogenerator Units	Strainer Unit, Screenwash, Comp: S	Addition	200712	1	68,994.92
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 2 - SB2 - EGSI - 1892	Production Steam	3120 Boiler Plant Equipment	Non-Unitized	Addition	200712	1	18,249.47
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 2 - SB2 - EGSI - 1892	Production Steam	3120 Boiler Plant Equipment	Chemical Feeder, Ammonia-Hydrazine	Addition	200712	1	93,884.54
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 2 - SB2 - EGSI - 1892	Production Steam	3120 Boiler Plant Equipment	Lubricating Oil Sys., Boiler Feed P	Addition	200712	1	45,241.22
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 2 - SB2 - EGSI - 1892	Production Steam	3110 Structures & Improvements	Instrument Air Supply, Comp: PS:In	Addition	200710	1	34,822.16
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 3 - SB3 - EGSI - 1893	Production Steam	3140 Turbogenerator Units	Pump, Driven By 25Hp + Motor, Scree	Addition	200712	2	205,114.00
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 3 - SB3 - EGSI - 1893	Production Steam	3110 Structures & Improvements	Air Dryer, Instrument Air, Comp - F	Addition	200711	1	22,260.64
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 4 - SB4 - EGSI - 1894	Production Steam	3120 Boiler Plant Equipment	Non-Unitized	Addition	200712	1	508,190.61
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 4 - SB4 - EGSI - 1894	Production Steam	3120 Boiler Plant Equipment	Reheater Section, Comp (Gas/Oil):	Addition	200710	35	635,348.71
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 4 - SB4 - EGSI - 1894	Production Steam	3110 Structures & Improvements	Non-Unitized	Addition	200712	1	61,851.36
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 5 - SB5 - EGSI - 1895	Production Steam	3140 Turbogenerator Units	Non-Unitized	Addition	200710	1	(121.99)
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 5 - SB5 - EGSI - 1895	Production Steam	3140 Turbogenerator Units	Fan, Driven By 25Hp + Motor, Circ W	Addition	200711	3	56,710.37
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 5 - SB5 - EGSI - 1895	Production Steam	3140 Turbogenerator Units	Generator, Stator: PS:Generator, S	Addition	200711	0	132,072.93
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 5 - SB5 - EGSI - 1895	Production Steam	3140 Turbogenerator Units	Monitor, Generator Core, Comp, Excl	Addition	200710	1	70,421.76
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 5 - SB5 - EGSI - 1895	Production Steam	3140 Turbogenerator Units	Pump, Driven By 25Hp + Motor, Cooli	Addition	200711	2	212,500.54
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 5 - SB5 - EGSI - 1895	Production Steam	3120 Boiler Plant Equipment	Non-Unitized	Addition	200710	1	(227.22)
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 5 - SB5 - EGSI - 1895	Production Steam	3120 Boiler Plant Equipment	Non-Unitized	Addition	200712	1	691.71
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 5 - SB5 - EGSI - 1895	Production Steam	3150 Accessory Electric Equipment	Battery Charger, Auxiliary Dc Power	Addition	200710	2	44,481.46
TX000: ENTERGY TEXAS, INC.	TX	Sabine SES - EGSI	Sabine Unit 5 - SB5 - EGSI - 1895	Production Steam	3150 Accessory Electric Equipment	Monitor, Turbo-Generator Vibration,	Addition	200711	1	348,432.11
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Chevyland - CHL - EGSI - 9002	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200712	1	(1.11)
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Chevyland - CHL - EGSI - 9002	Distribution Plant	3620 Stn Equip-Dist	Control & Relay Equip. For Scada:	Addition	200712	36	16,431.91
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Wilson Building - WLO - EGSI - 9335	General Plant	3900 Structures & Improvements	Air Conditioning & Heating-General:	Addition	200712	1	14,473.55
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Conroe S/C Office - CNO - EGSI - 9115	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200710	1	41,569.91
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Conroe S/C Office - CNO - EGSI - 9115	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200711	3	329,355.27
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Conroe S/C Office - CNO - EGSI - 9115	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200712	3	18,663.44
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Beaumont S/C Office - BEO - EGSI - 9045	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200710	1	134,343.92
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Beaumont S/C Office - BEO - EGSI - 9045	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200711	1	17,844.43
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Beaumont S/C Office - BEO - EGSI - 9045	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200712	1	116.01
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Cleveland S/C Office - CVS - EGSI - 9095	General Plant	3900 Structures & Improvements	Fence: GP:Fence	Addition	200712	0	(268.35)
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Winnie Service Center - WIN - EGSI - 9340	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200710	1	2,044.33
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	New Caney Office & S/C - NW1 - EGSI - 9260	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200710	1	43,327.90
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Silsbee Office Building - SLO - EGSI - 9290	General Plant	3900 Structures & Improvements	Parking Area: GP:Parking Lot, Comp	Addition	200711	1	15,784.36
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Navasota S/C Office/Garage - NVS - EGSI - 9255	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200711	1	48,145.87
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Navasota S/C Office/Garage - NVS - EGSI - 9255	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200712	1	304.60
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Navasota S/C Office/Garage - NVS - EGSI - 9255	General Plant	3900 Structures & Improvements	Building Superstructure: GP:Buildi	Addition	200712	1	161,802.22
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Dayton Service Center - New - DYT - EGSI - 9136	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200712	1	14,186.22
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Beaumont S/C Garage Building - BEG - EGSI - 9035	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200710	1	627.11
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Beaumont Liberty-Pearl Garage - LPG - EGSI - 9020	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200710	1	31,731.60
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Beaumont Liberty-Pearl Office - LPL - EGSI - 9025	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200711	1	410,305.59
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Beaumont Liberty-Pearl Office - LPL - EGSI - 9025	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200712	1	56,899.38
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Beaumont Liberty-Pearl Office - LPL - EGSI - 9025	General Plant	3900 Structures & Improvements	Fire Protection-Alarm System: GP:F	Addition	200712	0	(49.95)
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Helbig Portable Building No 1 - HL3 - EGSI - 9165	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200710	1	2,034.88
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Austin,Gov Affairs,Capital Cnt - AS2 - EGSI - 9007	General Plant	3900 Structures & Improvements	Leasehold Improvements: GP:Leaseho	Addition	200710	1	73,342.52
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Beaumont Edison Plaza Office B - EPL - EGSI - 9015	General Plant	3900 Structures & Improvements	Non-Unitized	Addition	200712	1	192,920.30
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Beaumont Edison Plaza Office B - EPL - EGSI - 9015	General Plant	3900 Structures & Improvements	Leasehold Improvements: GP:Leaseho	Addition	200711	1	8,436.80
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Beaumont Edison Plaza Office B - EPL - EGSI - 9015	General Plant	3900 Structures & Improvements	Leasehold Improvements: GP:Leaseho	Addition	200712	1	107,375.54
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Egsi-Tx It Electric Projects - BEO - EGSI - ITPRTE	General Plant	3912 Information Systems	Computer Equipment: GP:Computer Ha	Addition	200710	20	119,065.79
TX000: ENTERGY TEXAS, INC.	TX	Office Bld-EGSI-TX	Liberty Service Bldg & Storero - LPL - EGSI - 9220	General Plant	3900 Structures & Improvements	Air Conditioning & Heating-General:	Addition	200712	0	(1,189.98)
TX000: ENTERGY TEXAS, INC.	TX	Lewis Creek SES - EGSI	Lewis Creek Common - LWC - EGSI - 1850	Production Steam	3110 Structures & Improvements	Non-Unitized	Addition	200710	3	72,100.94
TX000: ENTERGY TEXAS, INC.	TX	Lewis Creek SES - EGSI	Lewis Creek Common - LWC - EGSI - 1850	Production Steam	3110 Structures & Improvements	Non-Unitized	Addition	200711	3	22,782.27
TX000: ENTERGY TEXAS, INC.	TX	Lewis Creek SES - EGSI	Lewis Creek Common - LWC - EGSI - 1850	Production Steam	3110 Structures & Improvements	Non-Unitized	Addition	200712	3	(9,674.11)
TX000: ENTERGY TEXAS, INC.	TX	Lewis Creek SES - EGSI	Lewis Creek Common - LWC - EGSI - 1850	Production Steam	3160 Misc Power Plant Equipment	Non-Unitized	Addition	200711	1	7,523.80
TX000: ENTERGY TEXAS, INC.	TX	Lewis Creek SES - EGSI	Lewis Creek Common - LWC - EGSI - 1850	Production Steam	3160 Misc Power Plant Equipment	Non-Unitized	Addition	200712	1	35,422.09
TX000: ENTERGY TEXAS, INC.	TX	Lewis Creek SES - EGSI	Lewis Creek Common - LWC - EGSI - 1850	Production Steam	3150 Accessory Electric Equipment	Non-Unitized	Addition	200711	1	1,526.00
TX000: ENTERGY TEXAS, INC.	TX	Lewis Creek SES - EGSI	Lewis Creek Unit 1 - LW1 - EGSI - 1851	Production Steam	3120 Boiler Plant Equipment	Non-Unitized	Addition	200711	1	60,846.64
TX000: ENTERGY TEXAS, INC.	TX	Lewis Creek SES - EGSI	Lewis Creek Unit 1 - LW1 - EGSI - 1851	Production Steam	3120 Boiler Plant Equipment	Non-Unitized	Addition	200712	1	2,905.99
TX000: ENTERGY TEXAS, INC.	TX	Lewis Creek SES - EGSI	Lewis Creek Unit 1 - LW1 - EGSI - 1851	Production Steam	3150 Accessory Electric Equipment	Non-Unitized	Addition	200711	1	20,830.03
TX000: ENTERGY TEXAS, INC.	TX	Distribution Subs-EGSI-TX	Forge - DSX - EGSI - 33192	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	8,494.52
TX000: ENTERGY TEXAS, INC.	TX	Distribution Subs-EGSI-TX	Gapac - DSX - EGSI - 33126	Distribution Plant	3620 Stn Equip-Dist	Animal Protection Devices: DS:Anim	Addition	200711	1	4,176.00
TX000: ENTERGY TEXAS, INC.	TX	Distribution Subs-EGSI-TX	Midway - DSX - EGSI - 33025	Distribution Plant	3620 Stn Equip-Dist	Tap Changer Control Devices: All V	Addition	200712	1	6,356.05
TX000: ENTERGY TEXAS, INC.	TX	Distribution Subs-EGSI-TX	Dry Dock - DSX - EGSI - 32154	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	8,244.01
TX000: ENTERGY TEXAS, INC.	TX	Distribution Subs-EGSI-TX	Franklin - DSX - EGSI - 33047	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	3,129.90
TX000: ENTERGY TEXAS, INC.	TX	Distribution Subs-EGSI-TX	Franklin - DSX - EGSI - 33047	Distribution Plant	3620 Stn Equip-Dist	Animal Protection Devices: DS:Anim	Addition	200711	1	3,458.25
TX000: ENTERGY TEXAS, INC.	TX	Distribution Subs-EGSI-TX	Lawson Substation - DSX - EGSI - 31008	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200710	1	24,534.31
TX000: ENTERGY TEXAS, INC.	TX	Distribution Subs-EGSI-TX	Kountze Substation - DSX - EGSI - 31110	Distribution Plant	3620 Stn Equip-Dist	Switch, Air Break 3 Pole: 13.8Kv, U	Addition	200711	2	14,174.47
TX000: ENTERGY TEXAS, INC.	TX	Distribution Subs-EGSI-TX	Trinity Substation - DSX - EGSI - 33093	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	3,611.63
TX000: ENTERGY TEXAS, INC.	TX	Distribution Subs-EGSI-TX	Trinity Substation - DSX - EGSI - 33093	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	415.70
TX000: ENTERGY TEXAS, INC.	TX	Distribution Subs-EGSI-TX	Groveton Substation - DSX - EGSI - 33033	Distribution Plant	3620 Stn Equip-Dist	Animal Protection Devices: DS:Anim	Addition	200711	1	3,719.25
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3700 Meters (Customer)	Non-Unitized	Addition	200710	1	4,417.67
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3700 Meters (Customer)	Non-Unitized	Addition	200711	2	15,843.30
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3700 Meters (Customer)	Non-Unitized	Addition	200712	1	69.43
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3700 Meters (Customer)	Meters, All Types, And Sizes: All	Addition	200712	6259	558,537.13
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3710 Inst On Cust Prem	Poles, Concrete: Concrete: DL:Lig	Transfer	200712	6	6,025.56
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Non-Unitized	Addition	200710	13	77,487.35
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Non-Unitized	Addition	200711	7	91,874.82
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Non-Unitized	Addition	200712	7	246.27
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Non-Unitized	Transfer	200712	34	4,137.67
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Conductor, Overhead: All Types, Al	Addition	200710	437	122.69
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Conductor, Overhead: All Types, Al	Addition	200711	225	139.65
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Conductor, Overhead: All Types, Al	Addition	200712	2110	9,187.54
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Conductor, Overhead: All Types, Al	Transfer	200710	510	306.22
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Conductor, Overhead: All Types, Al	Transfer	200712	72.87	258.68
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Conductor, Underground: All Types,	Addition	200710	10	41.52
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Conductor, Underground: All Types,	Addition	200712	756	17,547.84
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Lighting Fixtures: Roadway Lightin	Addition	200710	4	496.02
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Lighting Fixtures: Roadway Lightin	Addition	200712	78	19,992.79
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Lighting Fixtures: Roadway Lightin	Transfer	200712	25	3,869.52
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Poles, Concrete: Concrete: DL:Lig	Addition	200710	15	1,639.02
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Poles, Concrete: Concrete: DL:Lig	Addition	200712	11	37,562.96
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Poles, Concrete: Concrete: DL:Lig	Transfer	200710	12	1,808.66
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Poles, Concrete: Concrete: DL:Lig	Transfer	200712	0	4,000.00
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Poles, Fiberglass: Fiberglass: DL	Transfer	200712	25	7,509.82
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3730 St Ltng & Sgnl Sys	Poles, Metal: Metal: DL:Lighting	Addition	200712	6	33,934.51
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3732 Non Roadway Lighting	Non-Unitized	Addition	200710	5	30,942.24
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3732 Non Roadway Lighting	Non-Unitized	Addition	200711	5	27,889.52
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3732 Non Roadway Lighting	Non-Unitized	Addition	200712	4	191.12
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3732 Non Roadway Lighting	Lighting Fixtures (Non Roadway Ligh	Addition	200710	17	1,427.47
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3732 Non Roadway Lighting	Lighting Fixtures (Non Roadway Ligh	Addition	200711	35	(4,483.23)
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3732 Non Roadway Lighting	Lighting Fixtures (Non Roadway Ligh	Addition	200712	4	5,916.07
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3732 Non Roadway Lighting	Poles, Fiberglass (Non Roadway Ligh	Addition	200711	35	(9,233.52)
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3732 Non Roadway Lighting	Poles, Fiberglass (Non Roadway Ligh	Addition	200712	1	1,525.85
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Non-Unitized	Addition	200710	26	381,597.19
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Non-Unitized	Addition	200711	29	410,726.43
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Non-Unitized	Addition	200712	37	1,112,556.47
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Non-Unitized	Transfer	200712	81	468,095.41
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Pothead: DL:Pothead	Addition	200710	8	1,248.03
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Pothead: DL:Pothead	Addition	200711	6	703.75
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Pothead: DL:Pothead	Addition	200712	70	46,186.43
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Pothead: DL:Pothead	Transfer	200712	16	7,303.61
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Conductor Alum. Sgl, #1 & Smaller:	Addition	200712	24	2,839.40
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Conductor Alum. Sgl, 1/0-3/0: Alu	Addition	200710	78942	66,997.81
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Conductor Alum. Sgl, 1/0-3/0: Alu	Addition	200711	8412	16,804.70
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Conductor Alum. Sgl, 1/0-3/0: Alu	Addition	200712	44088	288,425.88
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Conductor Alum. Sgl, 1/0-3/0: Alu	Transfer	200710	58084	109,568.48
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Conductor Alum. Sgl, 1/0-3/0: Alu	Transfer	200712	34604	81,703.18
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Conductor Alum. Sgl, 500 & Above:	Addition	200710	3915	56,098.24
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Conductor Alum. Sgl, 500 & Above:	Addition	200712	8568	135,524.50
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Conductor Alum. Sgl, 500 & Above:	Transfer	200710	6068	60,280.70
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Conductor Alum. Sgl, 500 & Above:	Transfer	200712	4693	47,511.48
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Conductor Copper, #2 & Smaller: C	Addition	200712	6444	9,848.95
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Conductors, Ug Pri Ca #2 & Smaller:	Addition	200711	6785	5,580.98
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Conductors, Ug Pri Ca #2 & Smaller:	Addition	200712	23315	128,247.11
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Conductors, Ug Pri Ca #2 & Smaller:	Transfer	200710	25200	90,341.93
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Conductors, Ug Pri Ca 1/0 -3/0: Un	Addition	200712	1138	7,086.91
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Conductors, Ug Pri Ca 500 & Above:	Addition	200710	17773	491,513.70
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Conductors, Ug Pri Ca 500 & Above:	Addition	200711	15180	398,663.67
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Oil Switch, All Sizes: All Sizes:	Addition	200712	4	10,004.77
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Switchgear, Pad Mount, 34.5Kv: 34.	Addition	200710	1	3,362.11
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Switchgear, Pad Mount, 34.5Kv: 34.	Addition	200711	2	87,128.38
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Switchgear, Pad Mount, 34.5Kv: 34.	Addition	200712	10	496,615.62
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Switchgear, Pad Mount, 34.5Kv: 34.	Transfer	200710	2	57,232.43
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3670 Undrgrnd Cond & Devices	Switchgear, Pad Mount, 34.5Kv: 34.	Transfer	200712	1	39,256.56
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3653 Cost Of Clrng ROW - Dist	Non-Unitized	Addition	200712	1	5,548,786.55
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Non-Unitized	Addition	200710	36	1,070,700.00
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Non-Unitized	Addition	200711	32	1,324,866.38
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Non-Unitized	Addition	200712	56	1,044,759.84
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Non-Unitized	Transfer	200712	166	662,362.21
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Capacitor Unit: DL:Capacitors	Addition	200712	2	4,036.60
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Arrester, Lightning: Lightning: D	Addition	200710	29	4,301.50
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Arrester, Lightning: Lightning: D	Addition	200711	91	12,992.05
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Arrester, Lightning: Lightning: D	Addition	200712	190	52,717.21
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Arrester, Lightning: Lightning: D	Transfer	200710	30	5,489.87
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Arrester, Lightning: Lightning: D	Transfer	200712	16.24	2,989.27
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Capacitor Banks: Bank: DL:Capacit	Addition	200710	1	8,060.31
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Capacitor Banks: Bank: DL:Capacit	Addition	200712	2	14,139.73
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Regulator, 168 - 500 Kva: 168 - 50	Addition	200710	1	24,935.39
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Regulator, 168 - 500 Kva: 168 - 50	Transfer	200710	3	66,359.51
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Regulator, 50 - 167 Kva: 50 - 167	Addition	200712	2	141,252.07
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 10 Kva: Ohd, 10	Addition	200710	1	333.76
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 10 Kva: Ohd, 10	Addition	200712	9	9,619.85
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 10 Kva: Ohd, 10	Transfer	200710	1	267.98
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 15 Kva: Ohd, 15	Addition	200710	25	22,771.52
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 15 Kva: Ohd, 15	Addition	200711	9	10,980.01
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 15 Kva: Ohd, 15	Addition	200712	63	168,164.14
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 15 Kva: Ohd, 15	Transfer	200710	8	2,562.97
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 167 - 500 Kva: O	Addition	200710	16	78,938.01
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 167 - 500 Kva: O	Addition	200711	1	4,527.81
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 167 - 500 Kva: O	Addition	200712	44	457,828.95
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 167 - 500 Kva: O	Transfer	200710	12	35,967.60
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 25 Kva: Ohd, 25	Addition	200710	109	136,898.58
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 25 Kva: Ohd, 25	Addition	200711	30	46,418.10
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 25 Kva: Ohd, 25	Addition	200712	180	1,260,812.48
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 25 Kva: Ohd, 25	Transfer	200710	41	27,438.42
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 37.5 - 50 Kva: O	Addition	200710	54	107,026.94
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 37.5 - 50 Kva: O	Addition	200711	12	23,868.73
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 37.5 - 50 Kva: O	Addition	200712	109	1,157,969.24
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 37.5 - 50 Kva: O	Transfer	200710	29	21,912.02
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 75 - 150 Kva: Oh	Addition	200710	12	26,695.73
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 75 - 150 Kva: Oh	Addition	200711	5	13,988.35
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 75 - 150 Kva: Oh	Addition	200712	90	520,401.61
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 75 - 150 Kva: Oh	Transfer	200710	4	4,650.94
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Ohd, 75 - 150 Kva: Oh	Transfer	200712	9	21,808.52
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Pad Mt, 200 - 500 Kva:	Addition	200710	11	107,207.23
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Pad Mt, 200 - 500 Kva:	Addition	200712	10	260,368.18
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Pad Mt, 200 - 500 Kva:	Transfer	200710	1	10,078.26
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Pad Mt, 50 Kva & Less:	Addition	200710	14	19,578.18
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Pad Mt, 50 Kva & Less:	Addition	200711	24	72,980.71
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Pad Mt, 50 Kva & Less:	Addition	200712	32	180,012.10
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Pad Mt, 50 Kva & Less:	Transfer	200710	10	39,562.75
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Pad Mt, 50 Kva & Less:	Transfer	200712	1	3,956.27
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Pad Mt, 75 - 167 Kva:	Addition	200710	80	266,349.41
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Pad Mt, 75 - 167 Kva:	Addition	200711	18	77,303.36
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Pad Mt, 75 - 167 Kva:	Addition	200712	91	892,849.68
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Pad Mt, 75 - 167 Kva:	Transfer	200710	72	390,467.67
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Pad Mt, 75 - 167 Kva:	Transfer	200712	57	276,574.18
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Pad Mt, 750 - 2500 Kva	Addition	200710	1	51,588.45
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Pad Mt, 750 - 2500 Kva	Addition	200712	9	370,737.60
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Pad Mt, 750 - 2500 Kva	Transfer	200710	4	101,211.25
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3681 Line Transformers - Dist	Transformer, Pad Mt, 750 - 2500 Kva	Transfer	200712	2	61,531.27
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Non-Unitized	Addition	200710	27	206,792.33
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Non-Unitized	Addition	200711	20	768,486.85
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Non-Unitized	Addition	200712	44	406,255.71
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Non-Unitized	Transfer	200712	196	332,654.65
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Anchor: DL:Anchor	Addition	200710	52	21,540.29
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Anchor: DL:Anchor	Addition	200711	24	3,080.99
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Anchor: DL:Anchor	Addition	200712	503	127,768.37
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Crossarm: DL:Crossarm	Addition	200710	165	50,663.04
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Crossarm: DL:Crossarm	Addition	200711	132	71,763.21
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Crossarm: DL:Crossarm	Addition	200712	548	307,123.80
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Crossarm: DL:Crossarm	Transfer	200712	0	1.22
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Guy Wire: DL:Guy Wire	Addition	200710	2004	29,139.99
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Guy Wire: DL:Guy Wire	Addition	200711	426	3,475.41
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Guy Wire: DL:Guy Wire	Addition	200712	11446	163,425.52
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Platforms, Transformer Mounting: D	Addition	200710	1	2,540.70
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Platforms, Transformer Mounting: D	Addition	200712	6	21,104.83
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Platforms, Transformer Mounting: D	Transfer	200710	3	8,215.47
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Metal, 45' & Under: Metal, 4	Transfer	200710	4	2,939.64
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Metal, 46' To 70': Metal, 46	Addition	200710	1	2,036.47
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Metal, 46' To 70': Metal, 46	Addition	200712	1	6,817.04
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Metal, 46' To 70': Metal, 46	Transfer	200710	5	6,923.14
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 30' & Less: Wood, 30'	Addition	200710	4	1,046.22
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 30' & Less: Wood, 30'	Addition	200712	43	168,036.20
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 30' & Less: Wood, 30'	Transfer	200710	1	247.46
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 35': Wood, 35': DL:Po	Addition	200710	10	3,885.81
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 35': Wood, 35': DL:Po	Addition	200711	1	545.62
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 35': Wood, 35': DL:Po	Addition	200712	61	225,845.78
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 40': Wood, 40': DL:Po	Addition	200710	52	23,738.44
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 40': Wood, 40': DL:Po	Addition	200711	2	1,085.98
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 40': Wood, 40': DL:Po	Addition	200712	72	294,431.66
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 40': Wood, 40': DL:Po	Transfer	200710	26	14,086.16
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 40': Wood, 40': DL:Po	Transfer	200712	5	1,945.29
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 45': Wood, 45': DL:Po	Addition	200710	41	33,387.11
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 45': Wood, 45': DL:Po	Addition	200711	28	15,729.93
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 45': Wood, 45': DL:Po	Addition	200712	521	579,199.01
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 45': Wood, 45': DL:Po	Transfer	200710	92	53,810.52
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 45': Wood, 45': DL:Po	Transfer	200712	43.88	25,952.22
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 50' & Above: Wood, 50'	Addition	200710	34	25,163.73
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 50' & Above: Wood, 50'	Addition	200711	10	9,451.90
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 50' & Above: Wood, 50'	Addition	200712	64	155,848.59
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 50' & Above: Wood, 50'	Transfer	200710	15	18,707.37
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3640 Poles, Twrs & Fxtrs -Dist	Pole, Wood, 50' & Above: Wood, 50'	Transfer	200712	8.87	6,037.90
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3691 Services, Overhead - Dist	Non-Unitized	Addition	200710	13	21,658.05
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3691 Services, Overhead - Dist	Non-Unitized	Addition	200711	8	207,124.80
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3691 Services, Overhead - Dist	Non-Unitized	Addition	200712	12	3,241.68
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3691 Services, Overhead - Dist	Non-Unitized	Transfer	200712	41	4,312.08
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3691 Services, Overhead - Dist	Overhead Services: DL:Overhead Ser	Addition	200710	5994	11,922.99
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3691 Services, Overhead - Dist	Overhead Services: DL:Overhead Ser	Addition	200711	8185	14,762.94
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3691 Services, Overhead - Dist	Overhead Services: DL:Overhead Ser	Addition	200712	2555	1,805,818.46
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3691 Services, Overhead - Dist	Overhead Services: DL:Overhead Ser	Transfer	200710	519	1,628.26
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3692 Services, Underground-Dist	Non-Unitized	Addition	200710	23	64,535.69
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3692 Services, Underground-Dist	Non-Unitized	Addition	200711	23	70,226.12
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3692 Services, Underground-Dist	Non-Unitized	Addition	200712	31	63,533.89
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3692 Services, Underground-Dist	Non-Unitized	Transfer	200712	51	23,442.70
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3692 Services, Underground-Dist	Underground Services: DL:Undergrou	Addition	200710	18944	19,955.20
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3692 Services, Underground-Dist	Underground Services: DL:Undergrou	Addition	200711	8989	7,725.40
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3692 Services, Underground-Dist	Underground Services: DL:Undergrou	Addition	200712	171830	1,194,880.43
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3692 Services, Underground-Dist	Underground Services: DL:Undergrou	Transfer	200710	16516	57,288.62
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3692 Services, Underground-Dist	Underground Services: DL:Undergrou	Transfer	200712	11076	34,231.54
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Non-Unitized	Addition	200710	24	173,619.67
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Non-Unitized	Addition	200711	22	105,231.31
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Non-Unitized	Addition	200712	34	413,047.98
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Non-Unitized	Transfer	200712	72	310,652.06
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Conduit, Plastic: Plastic, All Siz	Addition	200710	3976	47,904.24
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Conduit, Plastic: Plastic, All Siz	Addition	200711	5917	2,884.56
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Conduit, Plastic: Plastic, All Siz	Addition	200712	5328	58,920.47
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Conduit, Plastic: Plastic, All Siz	Transfer	200710	10815	4,006.92
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Conduit, Plastic: Plastic, All Siz	Transfer	200712	1644	11,366.02
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Handhole/Pedestal/Junction Box: DL	Addition	200710	137	56,084.68
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Handhole/Pedestal/Junction Box: DL	Addition	200711	54	24,810.74
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Handhole/Pedestal/Junction Box: DL	Addition	200712	220	286,739.87
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Handhole/Pedestal/Junction Box: DL	Transfer	200710	127	108,276.13
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Handhole/Pedestal/Junction Box: DL	Transfer	200712	78	64,118.99
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Pad, Tfx Mounting: DL:Pad, Tfx Mou	Addition	200710	99	132,292.97
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Pad, Tfx Mounting: DL:Pad, Tfx Mou	Addition	200711	42	68,002.71
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Pad, Tfx Mounting: DL:Pad, Tfx Mou	Addition	200712	87	46,428.15
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Pad, Tfx Mounting: DL:Pad, Tfx Mou	Transfer	200710	82	135,473.13
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3660 Underground Conduit - Dist.	Pad, Tfx Mounting: DL:Pad, Tfx Mou	Transfer	200712	58	100,665.53
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Non-Unitized	Addition	200710	35	346,650.19
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Non-Unitized	Addition	200711	27	1,300,268.36
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Non-Unitized	Addition	200712	59	1,084,492.82
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Non-Unitized	Transfer	200712	237	1,134,295.08
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Pothead: DL:Pothead	Addition	200710	6	8,185.65
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Pothead: DL:Pothead	Addition	200712	9	10,548.79
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Switch, Fused: DL:Switch, Fused	Addition	200710	274	152,661.16
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Switch, Fused: DL:Switch, Fused	Addition	200711	94	38,494.93
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Switch, Fused: DL:Switch, Fused	Addition	200712	541	589,759.66
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Switch, Fused: DL:Switch, Fused	Transfer	200710	207	102,780.25
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Switch, Fused: DL:Switch, Fused	Transfer	200712	31.19	17,660.19
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Arrester, Lightning: Lightning: D	Addition	200710	38	11,672.11
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Arrester, Lightning: Lightning: D	Addition	200711	58	8,546.40
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Arrester, Lightning: Lightning: D	Addition	200712	293	127,206.09
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Arrester, Lightning: Lightning: D	Transfer	200710	174	35,161.10
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Arrester, Lightning: Lightning: D	Transfer	200712	16.97	4,106.75
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Alum. Sgl, #2 & Smaller:	Addition	200710	1594	9,429.85
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Alum. Sgl, #2 & Smaller:	Addition	200712	94483	99,707.74
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Alum. Sgl, 1/0-3/0: Alu	Addition	200710	20699	18,337.15
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Alum. Sgl, 1/0-3/0: Alu	Addition	200711	23704	15,830.31
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Alum. Sgl, 1/0-3/0: Alu	Addition	200712	138192	150,389.84
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Alum. Sgl, 1/0-3/0: Alu	Transfer	200710	20220	22,191.22
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Alum. Sgl, 1/0-3/0: Alu	Transfer	200712	2514.96	2,668.17
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Alum. Sgl, 4/0-477: Alu	Addition	200710	29984	53,128.19
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Alum. Sgl, 4/0-477: Alu	Addition	200711	3485	7,056.17
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Alum. Sgl, 4/0-477: Alu	Addition	200712	3703	11,549.23
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Alum. Sgl, 4/0-477: Alu	Transfer	200710	19403	23,148.39
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Alum. Sgl, 4/0-477: Alu	Transfer	200712	5223.57	4,938.71
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Alum. Sgl, 500 & Above:	Addition	200710	450	1,573.07
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Alum. Sgl, 500 & Above:	Addition	200711	153	1,892.74
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Alum. Sgl, 500 & Above:	Transfer	200710	54728	116,928.75
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Copper, #2 & Smaller: C	Addition	200710	1457	124,010.57
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Copper, #2 & Smaller: C	Addition	200711	710	21,580.95
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Copper, #2 & Smaller: C	Addition	200712	1810	77,865.40
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Copper, #2 & Smaller: C	Transfer	200710	915	2,975.07
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Copper, #2 & Smaller: C	Transfer	200712	196.27	4,704.55
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Copper, 1/0-3/0: Copper	Addition	200712	30	36.33
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Copper, 4/0-477: Copper	Addition	200711	570	5,150.72
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Conductor Copper, 4/0-477: Copper	Addition	200712	30	183.32
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Insulator, Primary: Primary: DL:I	Addition	200710	1000	132,334.75
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Insulator, Primary: Primary: DL:I	Addition	200711	457	47,453.62
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Insulator, Primary: Primary: DL:I	Addition	200712	1540	622,393.30
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Insulator, Primary: Primary: DL:I	Transfer	200712	0	(6,691.69)
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Recloser 3/0 15Kv & Over: 3/0 15Kv	Addition	200711	1	25,172.83
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Recloser 3/0 34.5Kv & Over: 3/0 34	Addition	200711	6	129,432.31
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Recloser 3/0 34.5Kv & Over: 3/0 34	Transfer	200710	1	6,576.57
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Recloser, 1Ph, 24Kv & Below: 1Ph,	Addition	200712	2	47,662.75
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Recloser, 3Ph, 34.5Kv & Below: 3Ph	Transfer	200710	1	12,224.98
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Switch, Air Break, Gang Operated:	Addition	200710	1	8,116.27
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Switch, Air Break, Gang Operated:	Addition	200711	10	63,054.60
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Switch, Air Break, Gang Operated:	Addition	200712	4	16,560.92
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Switch, Air Break, Gang Operated:	Transfer	200710	2	15,067.24
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Switch, Air Break, Gang Operated:	Transfer	200712	0.48	3,611.74
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Switch, Disconnect, Hookstick: DL:	Addition	200710	12	12,270.43
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Switch, Disconnect, Hookstick: DL:	Addition	200711	42	21,571.08
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Switch, Disconnect, Hookstick: DL:	Addition	200712	30	36,434.91
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Switch, Disconnect, Hookstick: DL:	Transfer	200710	36	33,095.33
TX000: ENTERGY TEXAS, INC.	TX	Distribution-Mass-EGSI-TX	Tx-Distribution Lines Electric - DTX - EGSI - 1500	Distribution Plant	3651 Overhd Cond & Devices - Dist	Switch, Disconnect, Hookstick: DL:	Transfer	200712	6.33	5,193.84
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Vfw Park To Kolbs - TTX - EGSI - 72499	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200710	3003	50,606.47
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Vfw Park To Kolbs - TTX - EGSI - 72499	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Assembly: Assembly:	Addition	200710	24	45,763.67
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Cow To Orange 69Kv Ln - TTX - EGSI - 77500	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	11	57,297.96
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Cow To Orange 69Kv Ln - TTX - EGSI - 77500	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	10	114,595.92
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Cow To Orange 69Kv Ln - TTX - EGSI - 77500	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	64	54,172.64
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Cow To Orange 69Kv Ln - TTX - EGSI - 77500	Transmission Plant	3561 Overhd Cond & Devices	Shieldwire - (All Sizes/Types): Al	Addition	200710	1200	16,147.61
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Echo To Front 69Kv Ln - TTX - EGSI - 77595	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	4	123,519.59
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Echo To Front 69Kv Ln - TTX - EGSI - 77595	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	4	163,912.23
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Echo To Front 69Kv Ln - TTX - EGSI - 77595	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200710	1800	70,189.56
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Echo To Front 69Kv Ln - TTX - EGSI - 77595	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	24	96,591.11
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Meeker To Poly 69Kv Ln - TTX - EGSI - 77141	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	1	2,106.16
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Meeker To Poly 69Kv Ln - TTX - EGSI - 77141	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	1	12,933.69
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Meeker To Poly 69Kv Ln - TTX - EGSI - 77141	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	6	1,805.31
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Cow 138Kv Ln - TTX - EGSI - 74492	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Other: Other: TL:Poles	Addition	200710	8	767,778.28
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Cow 138Kv Ln - TTX - EGSI - 74492	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	(115,515.91)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Cow 138Kv Ln - TTX - EGSI - 74492	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	(12,491.28)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Cow 138Kv Ln - TTX - EGSI - 74492	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	6,414.18
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Cow 138Kv Ln - TTX - EGSI - 74492	Transmission Plant	3561 Overhd Cond & Devices	Conductor (All Sizes): All Types,	Addition	200710	0	436,503.37
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Cow 138Kv Ln - TTX - EGSI - 74492	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200710	28800	42,091.38
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Cow 138Kv Ln - TTX - EGSI - 74492	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	24	820,392.54
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Cow 138Kv Ln - TTX - EGSI - 74492	Transmission Plant	3561 Overhd Cond & Devices	Shieldwire - (All Sizes/Types): Al	Addition	200710	4800	820,392.55
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Texaco 69Kv Ln - TTX - EGSI - 77079	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	2	1,896.13
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Texaco 69Kv Ln - TTX - EGSI - 77079	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	6	1,484.11
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Front 69Kv Ln - TTX - EGSI - 77508	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	8	6,729.55
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Front 69Kv Ln - TTX - EGSI - 77508	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	7	43,742.16
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Front 69Kv Ln - TTX - EGSI - 77508	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	45	13,459.14
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	China To Porter 230Kv Ln - TTX - EGSI - 74822	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200712	1	3,041.48
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	China To Porter 230Kv Ln - TTX - EGSI - 74822	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200712	1	6,181.51
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	China To Porter 230Kv Ln - TTX - EGSI - 74822	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200712	6	2,129.02
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #6 To Hull 69Kv Ln - TTX - EGSI - 77103R	Transmission Plant	3550 Poles & Fxtrs -Trans	Guy Wire: TL:Guy Wire	Addition	200712	0	13.68
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #6 To Hull 69Kv Ln - TTX - EGSI - 77103R	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200712	0	3,994.03
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #6 To Hull 69Kv Ln - TTX - EGSI - 77103R	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Assembly: Assembly:	Addition	200712	0	263.94
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	China To Raywood 138Kv Ln - TTX - EGSI - 74424	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	42,009.75
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	China To Raywood 138Kv Ln - TTX - EGSI - 74424	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	390.05
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	China To Raywood 138Kv Ln - TTX - EGSI - 74424	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	28,534.58
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	China To Raywood 138Kv Ln - TTX - EGSI - 74424	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	264.95
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	China To Raywood 138Kv Ln - TTX - EGSI - 74424	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Polymer Suspension: P	Addition	200712	8	4,837.00
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Echo To Str #380A 69Kv Ln - TTX - EGSI - 77081	Transmission Plant	3550 Poles & Fxtrs -Trans	X-Braces: TL:X-Braces	Addition	200710	2	31,682.52
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Echo To Str #380A 69Kv Ln - TTX - EGSI - 77081	Transmission Plant	3550 Poles & Fxtrs -Trans	Crossarm - Conductor (All Sizes/Typ	Addition	200710	3	18,820.38
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Echo To Str #380A 69Kv Ln - TTX - EGSI - 77081	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	2	363,166.95
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Echo To Str #380A 69Kv Ln - TTX - EGSI - 77081	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	1	12,294.69
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Echo To Str #380A 69Kv Ln - TTX - EGSI - 77081	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200710	6000	74,714.06
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Echo To Str #380A 69Kv Ln - TTX - EGSI - 77081	Transmission Plant	3561 Overhd Cond & Devices	Shieldwire - (All Sizes/Types): Al	Addition	200710	1800	52,725.40
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Savannah 69Kv Ln - TTX - EGSI - 77404	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	5	2,029.86
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Savannah 69Kv Ln - TTX - EGSI - 77404	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	4	3,220.57
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Savannah 69Kv Ln - TTX - EGSI - 77404	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	2,589.47
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Savannah 69Kv Ln - TTX - EGSI - 77404	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200710	800	690.15
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Savannah 69Kv Ln - TTX - EGSI - 77404	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	7	2,841.79
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches To Sabine 138Kv Ln - TTX - EGSI - 74172	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	4,536.65
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches To Sabine 138Kv Ln - TTX - EGSI - 74172	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	742.10
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Winfree 69Kv Ln - TTX - EGSI - 77505	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	2	52,336.25
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Winfree 69Kv Ln - TTX - EGSI - 77505	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	1	21,282.19
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Winfree 69Kv Ln - TTX - EGSI - 77505	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	9	17,641.84
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Pee Dee To Bryan 138Kv Ln - TTX - EGSI - 74059	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	2	55,099.50
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Pee Dee To Bryan 138Kv Ln - TTX - EGSI - 74059	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	2	17,080.17
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Orange 138Kv Ln - TTX - EGSI - 74514	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	(40,939.46)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Orange 138Kv Ln - TTX - EGSI - 74514	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	(16,364.97)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Orange 138Kv Ln - TTX - EGSI - 74514	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	9,109.64
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Orange 138Kv Ln - TTX - EGSI - 74514	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	(14,222.25)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Orange 138Kv Ln - TTX - EGSI - 74514	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	(5,685.14)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Orange 138Kv Ln - TTX - EGSI - 74514	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	3,164.66
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Orange 138Kv Ln - TTX - EGSI - 74527	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	(60,002.01)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Orange 138Kv Ln - TTX - EGSI - 74527	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	12,677.29
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Orange 138Kv Ln - TTX - EGSI - 74527	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	6,326.12
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Orange 138Kv Ln - TTX - EGSI - 74527	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	(41,729.68)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Orange 138Kv Ln - TTX - EGSI - 74527	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	8,816.71
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Orange 138Kv Ln - TTX - EGSI - 74527	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	4,399.63
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Stowell To Himex 69Kv Ln - TTX - EGSI - 77089R	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	(1,221,451.30)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Stowell To Himex 69Kv Ln - TTX - EGSI - 77089R	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	8,283.27
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Stowell To Himex 69Kv Ln - TTX - EGSI - 77089R	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	19,574.22
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Stowell To Himex 69Kv Ln - TTX - EGSI - 77089R	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	4	433,621.95
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Stowell To Himex 69Kv Ln - TTX - EGSI - 77089R	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	(663,498.56)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Stowell To Himex 69Kv Ln - TTX - EGSI - 77089R	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	4,499.52
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Stowell To Himex 69Kv Ln - TTX - EGSI - 77089R	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	9	412,358.89
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Stowell To Himex 69Kv Ln - TTX - EGSI - 77089R	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Polymer Suspension: P	Addition	200710	3	2,630.93
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #595 To Aplha 69Kv Ln - TTX - EGSI - 77502	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Other: Other: TL:Poles	Addition	200710	1	12,169.14
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #595 To Aplha 69Kv Ln - TTX - EGSI - 77502	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200710	1800	980.80
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #595 To Aplha 69Kv Ln - TTX - EGSI - 77502	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	3	3,882.11
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #6 To Hardin 69Kv Ln - TTX - EGSI - 77594R	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	2	18,375.91
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #6 To Hardin 69Kv Ln - TTX - EGSI - 77594R	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	2	30,504.00
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #6 To Hardin 69Kv Ln - TTX - EGSI - 77594R	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200710	3600	8,177.28
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #6 To Hardin 69Kv Ln - TTX - EGSI - 77594R	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	15	20,443.20
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Metro To Oakridge 138Kv Ln - TTX - EGSI - 74169	Transmission Plant	3580 Undergrnd Cond&Devices	Conductor - (All Sizes/Types): All	Transfer	200712	5916	321,997.60
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches To Evadale 138Kv Ln - TTX - EGSI - 74017	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	4,760.26
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches To Evadale 138Kv Ln - TTX - EGSI - 74017	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	(7,349.61)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches To Evadale 138Kv Ln - TTX - EGSI - 74017	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	991.12
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches To Evadale 138Kv Ln - TTX - EGSI - 74017	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	(1,530.24)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orangebulk To Echo 69Kv Ln - TTX - EGSI - 77525	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	290.44
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orangebulk To Echo 69Kv Ln - TTX - EGSI - 77525	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	368.83
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Elizabeth To Helbig 69Kv Ln - TTX - EGSI - 77585	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	1	7,548.41
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Elizabeth To Helbig 69Kv Ln - TTX - EGSI - 77585	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	3	1,958.16
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Line #470 69Kv Ln - TTX - EGSI - 77467	Transmission Plant	3550 Poles & Fxtrs -Trans	Crossarm - Conductor (All Sizes/Typ	Addition	200710	1	489.90
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Line #470 69Kv Ln - TTX - EGSI - 77467	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	1	1,224.74
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Line #470 69Kv Ln - TTX - EGSI - 77467	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	1	3,827.34
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Line #470 69Kv Ln - TTX - EGSI - 77467	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	7	734.85
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #191 To P.S.E. 69Kv Ln - TTX - EGSI - 77446	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	4	7,336.24
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #191 To P.S.E. 69Kv Ln - TTX - EGSI - 77446	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	4	15,130.98
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #191 To P.S.E. 69Kv Ln - TTX - EGSI - 77446	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	24	3,668.10
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Firestone 69Kv Ln - TTX - EGSI - 77506	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	8	17,795.30
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Firestone 69Kv Ln - TTX - EGSI - 77506	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	8	35,070.81
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Firestone 69Kv Ln - TTX - EGSI - 77506	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	48	17,795.30
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Firestone 69Kv Ln - TTX - EGSI - 77506	Transmission Plant	3561 Overhd Cond & Devices	Shieldwire - (All Sizes/Types): Al	Addition	200710	1200	3,336.62
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Gulfpoly 138Kv Ln - TTX - EGSI - 74584	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	3	114,247.88
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Gulfpoly 138Kv Ln - TTX - EGSI - 74584	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	2	57,290.19
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Gulfpoly 138Kv Ln - TTX - EGSI - 74584	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	15	50,128.95
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Gulfpoly 138Kv Ln - TTX - EGSI - 74584	Transmission Plant	3561 Overhd Cond & Devices	Shieldwire - (All Sizes/Types): Al	Addition	200710	3000	59,469.67
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Rivtrin To Pee Dee 138Kv Ln - TTX - EGSI - 74509	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	17,142.14
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Rivtrin To Pee Dee 138Kv Ln - TTX - EGSI - 74509	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	16,608.53
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Westend To Parkdale 69Kv Ln - TTX - EGSI - 77408	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	2	10,020.18
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Westend To Parkdale 69Kv Ln - TTX - EGSI - 77408	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	1	43,539.79
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Westend To Parkdale 69Kv Ln - TTX - EGSI - 77408	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200710	600	644.17
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Westend To Parkdale 69Kv Ln - TTX - EGSI - 77408	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	10	7,157.25
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Bayshore To Stowell 138Kv Ln - TTX - EGSI - 74475	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	5,387.55
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Bayshore To Stowell 138Kv Ln - TTX - EGSI - 74475	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	11	160,031.42
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Bayshore To Stowell 138Kv Ln - TTX - EGSI - 74475	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	4,908.37
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Bayshore To Stowell 138Kv Ln - TTX - EGSI - 74475	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	9	26,989.43
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Bayshore To Stowell 138Kv Ln - TTX - EGSI - 74475	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Polymer Suspension: P	Addition	200710	3	22,730.37
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Crockett To West End 69Kv Ln - TTX - EGSI - 77407	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	2	823.83
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Crockett To West End 69Kv Ln - TTX - EGSI - 77407	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	2	1,853.63
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Crockett To West End 69Kv Ln - TTX - EGSI - 77407	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	12	823.85
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Doucette To Sam Dam 138Kv Ln - TTX - EGSI - 74097	Transmission Plant	3563 Overhd Cond & Dev - Clr&Gra	Non-Unitized	Addition	200712	1	28,035.10
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Gallier To Elizabeth 69Kv Ln - TTX - EGSI - 77468	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	47.40
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Gallier To Elizabeth 69Kv Ln - TTX - EGSI - 77468	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	103.96
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Jayhawker-Security 138Kv Sub - TTX - EGSI - 74811	Transmission Plant	3540 Twrs & Fxtrs-Trans	Non-Unitized	Addition	200710	1	7,494.55
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Jayhawker-Security 138Kv Sub - TTX - EGSI - 74811	Transmission Plant	3540 Twrs & Fxtrs-Trans	Non-Unitized	Addition	200711	1	2,557.84
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Jayhawker-Security 138Kv Sub - TTX - EGSI - 74811	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	116,275.46
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Jayhawker-Security 138Kv Sub - TTX - EGSI - 74811	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	39,684.07
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Jayhawker-Security 138Kv Sub - TTX - EGSI - 74811	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	29,410.82
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Jayhawker-Security 138Kv Sub - TTX - EGSI - 74811	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	10,037.73
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Jayhawker-Security 138Kv Sub - TTX - EGSI - 74811	Transmission Plant	3562 Overhd Cond & Devs - Dmgs	Non-Unitized	Addition	200710	1	4,015.47
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Jayhawker-Security 138Kv Sub - TTX - EGSI - 74811	Transmission Plant	3562 Overhd Cond & Devs - Dmgs	Non-Unitized	Addition	200711	1	1,370.44
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	LN 55 Sour Lake Sub to Batson - TTX -EGSI - 77055	Transmission Plant	3550 Poles & Fxtrs -Trans	Guy Wire: TL:Guy Wire	Addition	200710	200	459.03
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	LN 55 Sour Lake Sub to Batson - TTX -EGSI - 77055	Transmission Plant	3550 Poles & Fxtrs -Trans	X-Braces: TL:X-Braces	Addition	200710	3	2,868.94
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	LN 55 Sour Lake Sub to Batson - TTX -EGSI - 77055	Transmission Plant	3550 Poles & Fxtrs -Trans	Crossarm - Conductor (All Sizes/Typ	Addition	200710	3	2,295.18
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	LN 55 Sour Lake Sub to Batson - TTX -EGSI - 77055	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	2	3,825.27
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	LN 55 Sour Lake Sub to Batson - TTX -EGSI - 77055	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	2	12,097.44
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	LN 56 Batson Sub to Daisetta - TTX - EGSI - 77056	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	1	21,612.62
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	LN 56 Batson Sub to Daisetta - TTX - EGSI - 77056	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	1	67,062.73
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	LN 56 Batson Sub to Daisetta - TTX - EGSI - 77056	Transmission Plant	3561 Overhd Cond & Devices	Conductor (All Sizes): All Types,	Addition	200710	9000	17,162.99
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	LN 56 Batson Sub to Daisetta - TTX - EGSI - 77056	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	6	7,627.98
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	LN 57 Daisetta Sub to Raywood - TTX - EGSI- 77057	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	1	9,604.67
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	LN 57 Daisetta Sub to Raywood - TTX - EGSI- 77057	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	2	33,022.24
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	LN 57 Daisetta Sub to Raywood - TTX - EGSI- 77057	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	12	50,318.78
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #117 To Pabtex 69Kv Ln - TTX - EGSI - 77189R	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	(47,948.18)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #117 To Pabtex 69Kv Ln - TTX - EGSI - 77189R	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	(37,634.66)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Stowell To Big Hill 138Kv Ln - TTX - EGSI - 74151	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	1,417.25
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Stowell To Big Hill 138Kv Ln - TTX - EGSI - 74151	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	8,620.28
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Stowell To Big Hill 138Kv Ln - TTX - EGSI - 74151	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	3,331.40
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Stowell To Big Hill 138Kv Ln - TTX - EGSI - 74151	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	322.17
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Stowell To Big Hill 138Kv Ln - TTX - EGSI - 74151	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	1,959.56
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Stowell To Big Hill 138Kv Ln - TTX - EGSI - 74151	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	2	19,171.95
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Tamina To Oak Ridge 138Kv Ln - TTX - EGSI - 74582	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Spacer Damper (Cond. H	Addition	200711	30	5,942.53
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Amelia Bulk To China 230Kv Ln - TTX - EGSI - 72599	Transmission Plant	3550 Poles & Fxtrs -Trans	Guy Wire: TL:Guy Wire	Addition	200710	250	13,452.70
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Amelia Bulk To China 230Kv Ln - TTX - EGSI - 72599	Transmission Plant	3550 Poles & Fxtrs -Trans	X-Braces: TL:X-Braces	Addition	200710	10	18,840.22
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Amelia Bulk To China 230Kv Ln - TTX - EGSI - 72599	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	1	26,211.55
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Amelia Bulk To China 230Kv Ln - TTX - EGSI - 72599	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	1	29,897.22
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Amelia Bulk To China 230Kv Ln - TTX - EGSI - 72599	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200710	10800	22,298.31
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Amelia Bulk To China 230Kv Ln - TTX - EGSI - 72599	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	6	19,349.76
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Amelia Bulk To China 230Kv Ln - TTX - EGSI - 72599	Transmission Plant	3561 Overhd Cond & Devices	Shieldwire - (All Sizes/Types): Al	Addition	200710	600	27,851.67
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Carroll Street To So Beaumont - TTX - EGSI - 74828	Transmission Plant	3550 Poles & Fxtrs -Trans	Guy Wire: TL:Guy Wire	Addition	200712	0	(16.78)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Carroll Street To So Beaumont - TTX - EGSI - 74828	Transmission Plant	3550 Poles & Fxtrs -Trans	Anchors - (All Types): TL:Anchor	Addition	200712	0	(17.56)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Carroll Street To So Beaumont - TTX - EGSI - 74828	Transmission Plant	3550 Poles & Fxtrs -Trans	Foundations - Concrete: Concrete:	Addition	200712	0	(88.02)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Carroll Street To So Beaumont - TTX - EGSI - 74828	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200712	0	(52.40)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Carroll Street To So Beaumont - TTX - EGSI - 74828	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200712	0	(19.38)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Carroll Street To So Beaumont - TTX - EGSI - 74828	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200712	0	(76.44)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Carroll Street To So Beaumont - TTX - EGSI - 74828	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Assembly: Assembly:	Addition	200712	0	(59.72)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Dupont Beaumont To Kolbs 69Kv - TTX - EGSI - 77461	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	3	14,878.84
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Dupont Beaumont To Kolbs 69Kv - TTX - EGSI - 77461	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	2	16,080.06
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Dupont Beaumont To Kolbs 69Kv - TTX - EGSI - 77461	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	15	7,191.47
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Elizabeth To Amelia Bulk 69Kv - TTX - EGSI - 77545	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	7	5,529.60
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Elizabeth To Amelia Bulk 69Kv - TTX - EGSI - 77545	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200712	3	43,684.02
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Elizabeth To Amelia Bulk 69Kv - TTX - EGSI - 77545	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	7	6,314.84
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Elizabeth To Amelia Bulk 69Kv - TTX - EGSI - 77545	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	52	3,573.02
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Elizabeth To Amelia Bulk 69Kv - TTX - EGSI - 77545	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200712	9	8,995.60
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Grimes To Adjacent To College - TTX - EGSI - 74490	Transmission Plant	3550 Poles & Fxtrs -Trans	Crossarm - Conductor (All Sizes/Typ	Addition	200711	1	2,819.67
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Grimes To Adjacent To College - TTX - EGSI - 74490	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Polymer Suspension: P	Addition	200711	3	2,800.73
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Georgetown 230Kv Ln - TTX - EGSI - 72421	Transmission Plant	3550 Poles & Fxtrs -Trans	X-Braces: TL:X-Braces	Addition	200710	4	662.60
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Georgetown 230Kv Ln - TTX - EGSI - 72421	Transmission Plant	3550 Poles & Fxtrs -Trans	Crossarm - Conductor (All Sizes/Typ	Addition	200711	5	6,729.49
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Georgetown 230Kv Ln - TTX - EGSI - 72421	Transmission Plant	3550 Poles & Fxtrs -Trans	Crossarm - Shieldwire (All Sizes/Ty	Addition	200711	5	1,707.51
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Georgetown 230Kv Ln - TTX - EGSI - 72421	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	1	7,122.72
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Georgetown 230Kv Ln - TTX - EGSI - 72421	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200711	10	116,510.56
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Georgetown 230Kv Ln - TTX - EGSI - 72421	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	3	6,137.43
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Georgetown 230Kv Ln - TTX - EGSI - 72421	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Polymer Suspension: P	Addition	200711	15	56,307.71
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Jacinto To Line #582 138Kv Ln - TTX - EGSI - 74571	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200711	4	27,219.88
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Jacinto To Line #582 138Kv Ln - TTX - EGSI - 74571	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200711	12	7,446.19
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Jacinto To Line #582 138Kv Ln - TTX - EGSI - 74571	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Polymer Suspension: P	Addition	200711	12	4,798.64
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Jacinto To Line #582 138Kv Ln - TTX - EGSI - 74571	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Spacer Damper (Cond. H	Addition	200711	30	23,426.47
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Jacinto To Line #582 138Kv Ln - TTX - EGSI - 74571	Transmission Plant	3561 Overhd Cond & Devices	Structure Grounding System: Struct	Addition	200711	8	661.88
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #505 To Bridge City 69Kv - TTX - EGSI - 77517	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	45,298.81
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #505 To Bridge City 69Kv - TTX - EGSI - 77517	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	1	7,249.35
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #505 To Bridge City 69Kv - TTX - EGSI - 77517	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	11,330.27
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Longmire To Navasota 138Kv Ln - TTX - EGSI - 74096	Transmission Plant	3550 Poles & Fxtrs -Trans	Guy Wire: TL:Guy Wire	Addition	200712	16	108.41
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Longmire To Navasota 138Kv Ln - TTX - EGSI - 74096	Transmission Plant	3550 Poles & Fxtrs -Trans	Anchors - (All Types): TL:Anchor	Addition	200712	16	141.20
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Longmire To Navasota 138Kv Ln - TTX - EGSI - 74096	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200712	2	208.92
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Longmire To Navasota 138Kv Ln - TTX - EGSI - 74096	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200712	2158	107.65
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Longmire To Navasota 138Kv Ln - TTX - EGSI - 74096	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Assembly: Assembly:	Addition	200712	23	285.69
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Longmire To Navasota 138Kv Ln - TTX - EGSI - 74096	Transmission Plant	3561 Overhd Cond & Devices	Shieldwire - (All Sizes/Types): Al	Addition	200712	1300.68	37.81
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Magnolia To Kolbs Sub 69Kv Ln - TTX - EGSI - 77497	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	2	14,720.12
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Magnolia To Kolbs Sub 69Kv Ln - TTX - EGSI - 77497	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	2	12,811.98
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Magnolia To Kolbs Sub 69Kv Ln - TTX - EGSI - 77497	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	12	17,991.27
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Magnolia To Kolbs Sub 69Kv Ln - TTX - EGSI - 77497	Transmission Plant	3561 Overhd Cond & Devices	Shieldwire - (All Sizes/Types): Al	Addition	200710	1800	6,542.26
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Meeker To Goodyear Cheek 69Kv - TTX - EGSI - 77462	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	(99,527.41)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Meeker To Goodyear Cheek 69Kv - TTX - EGSI - 77462	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	124.60
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Meeker To Goodyear Cheek 69Kv - TTX - EGSI - 77462	Transmission Plant	3550 Poles & Fxtrs -Trans	X-Braces: TL:X-Braces	Addition	200710	8	499.42
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Meeker To Goodyear Cheek 69Kv - TTX - EGSI - 77462	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	1	1,123.73
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Meeker To Goodyear Cheek 69Kv - TTX - EGSI - 77462	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	1	2,653.18
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Meeker To Goodyear Cheek 69Kv - TTX - EGSI - 77462	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	(55,027.52)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Meeker To Goodyear Cheek 69Kv - TTX - EGSI - 77462	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	68.89
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Meeker To Goodyear Cheek 69Kv - TTX - EGSI - 77462	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	6	2,391.00
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Meeker To Goodyear Cheek 69Kv - TTX - EGSI - 77462	Transmission Plant	3561 Overhd Cond & Devices	Shieldwire - (All Sizes/Types): Al	Addition	200710	1200	936.42
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Mid County To Port Acres Bulk - TTX - EGSI - 72591	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	(771.43)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Mid County To Port Acres Bulk - TTX - EGSI - 72591	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	13	412,321.25
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Mid County To Port Acres Bulk - TTX - EGSI - 72591	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	12	500,071.66
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Mid County To Port Acres Bulk - TTX - EGSI - 72591	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	(1,157.15)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Mid County To Port Acres Bulk - TTX - EGSI - 72591	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200710	1800	211,560.98
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Mid County To Port Acres Bulk - TTX - EGSI - 72591	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	75	238,483.44
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Mid County To Port Acres Bulk - TTX - EGSI - 72591	Transmission Plant	3580 Undergrnd Cond&Devices	Non-Unitized	Transfer	200712	1	(385.71)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Mid County To Port Acres Bulk - TTX - EGSI - 72591	Transmission Plant	3580 Undergrnd Cond&Devices	Conductor - (All Sizes/Types): All	Transfer	200712	1900	126.86
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Mobil Hebert To Explorer 69Kv - TTX - EGSI - 77564	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	2	1,196.29
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Mobil Hebert To Explorer 69Kv - TTX - EGSI - 77564	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	2	1,225.47
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Mobil Hebert To Explorer 69Kv - TTX - EGSI - 77564	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	12	1,079.55
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches Station To So Beaumont - TTX - EGSI - 74457	Transmission Plant	3550 Poles & Fxtrs -Trans	Guy Wire: TL:Guy Wire	Addition	200712	0	(53.57)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches Station To So Beaumont - TTX - EGSI - 74457	Transmission Plant	3550 Poles & Fxtrs -Trans	Anchors - (All Types): TL:Anchor	Addition	200712	0	(2,054.72)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches Station To So Beaumont - TTX - EGSI - 74457	Transmission Plant	3550 Poles & Fxtrs -Trans	Crossarm - Shieldwire (All Sizes/Ty	Addition	200712	0	(39.10)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches Station To So Beaumont - TTX - EGSI - 74457	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200712	0	(4,261.38)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches Station To So Beaumont - TTX - EGSI - 74457	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200712	0	(1,671.16)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches Station To So Beaumont - TTX - EGSI - 74457	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200712	0	(782.87)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches Station To So Beaumont - TTX - EGSI - 74457	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Assembly: Assembly:	Addition	200712	0	(1,698.02)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches Station To So Beaumont - TTX - EGSI - 74457	Transmission Plant	3561 Overhd Cond & Devices	Shieldwire - (All Sizes/Types): Al	Addition	200712	0	(152.78)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches Station To So Beaumont - TTX - EGSI - 74457	Transmission Plant	3590 Roads & Trails - Trans	Roads And Trails: TL:Roads, +/- Wa	Addition	200712	0	(28.17)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches Station To So Beaumont - TTX - EGSI - 74457	Transmission Plant	3562 Overhd Cond & Devs - Dmgs	Right Of Way Damages: TL:Right Of	Addition	200712	0	(230.05)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Cheek 138Kv - TTX - EGSI - 74088	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	(106,522.13)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Cheek 138Kv - TTX - EGSI - 74088	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	66,801.69
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Cheek 138Kv - TTX - EGSI - 74088	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	48,130.08
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Cheek 138Kv - TTX - EGSI - 74088	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	(55,343.89)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Cheek 138Kv - TTX - EGSI - 74088	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	34,707.04
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Cheek 138Kv - TTX - EGSI - 74088	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	25,006.14
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Amelia Bulk To Cypress 230Kv L - TTX - EGSI - 72488	Transmission Plant	3550 Poles & Fxtrs -Trans	Crossarm - Conductor (All Sizes/Typ	Addition	200710	1	39.03
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Amelia Bulk To Cypress 230Kv L - TTX - EGSI - 72488	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	2	1,177.80
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Amelia Bulk To Cypress 230Kv L - TTX - EGSI - 72488	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Polymer Suspension: P	Addition	200710	3	928.49
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Amelia Bulk To Raywood 69Kv Ln - TTX - EGSI - 77006	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	12	206,480.22
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Big Hill To Div Ln To Mid Coun - TTX - EGSI - 74552	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	(93,355.18)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Big Hill To Div Ln To Mid Coun - TTX - EGSI - 74552	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	10,345.94
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Big Hill To Div Ln To Mid Coun - TTX - EGSI - 74552	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	10,154.88
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Big Hill To Div Ln To Mid Coun - TTX - EGSI - 74552	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	(17,839.17)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Big Hill To Div Ln To Mid Coun - TTX - EGSI - 74552	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	1,977.00
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Big Hill To Div Ln To Mid Coun - TTX - EGSI - 74552	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	1,940.49
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Bridge City To Firestone Orang - TTX - EGSI - 77575	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	385,507.62
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Bridge City To Firestone Orang - TTX - EGSI - 77575	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	(395,524.73)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Bridge City To Firestone Orang - TTX - EGSI - 77575	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	62,039.53
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Bridge City To Firestone Orang - TTX - EGSI - 77575	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	4	17,486.55
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Bridge City To Firestone Orang - TTX - EGSI - 77575	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	3	18,706.51
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Bridge City To Firestone Orang - TTX - EGSI - 77575	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	233,432.19
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Bridge City To Firestone Orang - TTX - EGSI - 77575	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	(239,497.74)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Bridge City To Firestone Orang - TTX - EGSI - 77575	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	37,566.12
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Bridge City To Firestone Orang - TTX - EGSI - 77575	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200710	1800	17,232.36
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Bridge City To Firestone Orang - TTX - EGSI - 77575	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	21	19,062.34
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Carlyss To Div Ln To Sabine (T - TTX - EGSI - 72428	Transmission Plant	3540 Twrs & Fxtrs-Trans	Aviation Lighting: TL:Aviation Lig	Addition	200710	1	22,561.40
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Carlyss To Div Ln To Sabine (T - TTX - EGSI - 72428	Transmission Plant	3540 Twrs & Fxtrs-Trans	Tower, Deadend: Deadend: TL:Tower	Addition	200710	1	9,743.80
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Carlyss To Div Ln To Sabine (T - TTX - EGSI - 72428	Transmission Plant	3540 Twrs & Fxtrs-Trans	Tower, River Crossing: River Cross	Addition	200710	1	1,446,248.80
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Carlyss To Div Ln To Sabine (T - TTX - EGSI - 72428	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	222,989.81
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Carlyss To Div Ln To Sabine (T - TTX - EGSI - 72428	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	(370,652.14)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Carlyss To Div Ln To Sabine (T - TTX - EGSI - 72428	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	163,175.06
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Carlyss To Div Ln To Sabine (T - TTX - EGSI - 72428	Transmission Plant	3561 Overhd Cond & Devices	Conductor (All Sizes): All Types,	Addition	200710	3200	1,570.07
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Carlyss To Div Ln To Sabine (T - TTX - EGSI - 72428	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Polymer Suspension: P	Addition	200710	8	202,786.19
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Doucette To Diviln To Corrigan - TTX - EGSI - 74093	Transmission Plant	3563 Overhd Cond & Dev - Clr&Gra	Non-Unitized	Addition	200712	1	12,823.99
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Dupont Dee To Goodrich 69Kv Ln - TTX - EGSI - 77498	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	15	143,742.10
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Dupont Dee To Goodrich 69Kv Ln - TTX - EGSI - 77498	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	45	91,690.80
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Groves To Atlantic Bulk 69Kv L - TTX - EGSI - 77109	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	3	26,591.73
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Groves To Atlantic Bulk 69Kv L - TTX - EGSI - 77109	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	3	162,166.01
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Groves To Atlantic Bulk 69Kv L - TTX - EGSI - 77109	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200710	1800	2,871.91
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Groves To Atlantic Bulk 69Kv L - TTX - EGSI - 77109	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	18	19,146.06
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Gulf Oil To Fort Worth 69Kv Ln - TTX - EGSI - 77191	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	1	27,218.43
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Gulf Oil To Fort Worth 69Kv Ln - TTX - EGSI - 77191	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	3	14,166.35
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Amelia Bulk 230Kv Ln - TTX - EGSI - 72422	Transmission Plant	3550 Poles & Fxtrs -Trans	Guy Wire: TL:Guy Wire	Addition	200712	0	(0.03)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Amelia Bulk 230Kv Ln - TTX - EGSI - 72422	Transmission Plant	3550 Poles & Fxtrs -Trans	Anchors - (All Types): TL:Anchor	Addition	200712	0	(0.03)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Amelia Bulk 230Kv Ln - TTX - EGSI - 72422	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200712	0	(0.01)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Amelia Bulk 230Kv Ln - TTX - EGSI - 72422	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200712	0	(2.02)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Amelia Bulk 230Kv Ln - TTX - EGSI - 72422	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200712	0	(0.49)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Amelia Bulk 230Kv Ln - TTX - EGSI - 72422	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Assembly: Assembly:	Addition	200712	0	(0.16)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Amelia Bulk 230Kv Ln - TTX - EGSI - 72422	Transmission Plant	3561 Overhd Cond & Devices	Shieldwire - (All Sizes/Types): Al	Addition	200712	0	(0.03)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Helbig To Amelia Bulk 230Kv Ln - TTX - EGSI - 72422	Transmission Plant	3562 Overhd Cond & Devs - Dmgs	Right Of Way Damages: TL:Right Of	Addition	200712	0	(0.03)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Jacinto To Div Line To China 2 - TTX - EGSI - 72568	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	3,651.67
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Atlantic Bulk 69Kv Ln - TTX - EGSI - 77117	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	1	5,494.33
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Atlantic Bulk 69Kv Ln - TTX - EGSI - 77117	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	1	33,739.91
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Atlantic Bulk 69Kv Ln - TTX - EGSI - 77117	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	6	4,709.44
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Port Acres Bulk 230Kv - TTX - EGSI - 72554	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	3,637.12
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Port Acres Bulk 230Kv - TTX - EGSI - 72554	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	2	5,354.45
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Port Acres Bulk 230Kv - TTX - EGSI - 72554	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	2,459.84
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Port Acres Bulk 230Kv - TTX - EGSI - 72554	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	38,501.54
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Port Acres Bulk 230Kv - TTX - EGSI - 72554	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	3	137,988.00
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Port Acres Bulk 230Kv - TTX - EGSI - 72554	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	2	98,143.15
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Port Acres Bulk 230Kv - TTX - EGSI - 72554	Transmission Plant	3580 Undergrnd Cond&Devices	Non-Unitized	Transfer	200712	1	(349.21)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Port Acres Bulk 230Kv - TTX - EGSI - 72554	Transmission Plant	3580 Undergrnd Cond&Devices	Conductor - (All Sizes/Types): All	Transfer	200712	1650	68.54
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Port Neches Bulk 69Kv - TTX - EGSI - 77077	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	2	793.10
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Kolbs To Port Neches Bulk 69Kv - TTX - EGSI - 77077	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	6	414.23
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Lewis Creek - Peach Creek138Kv - TTX - EGSI - 74824	Transmission Plant	3550 Poles & Fxtrs -Trans	Anchors - (All Types): TL:Anchor	Addition	200711	2	8,143.70
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Lewis Creek To Huntsville 138K - TTX - EGSI - 74087	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	7,005.20
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Lewis Creek To Huntsville 138K - TTX - EGSI - 74087	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	14,889.85
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Lewis Creek To Jacinto 138Kv L - TTX - EGSI - 74524	Transmission Plant	3563 Overhd Cond & Dev - Clr&Gra	Non-Unitized	Addition	200712	1	25,883.84
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Lewis Creek To Rivtrin 138Kv L - TTX - EGSI - 74487	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	12,067.88
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Lewis Creek To Rivtrin 138Kv L - TTX - EGSI - 74487	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	10,377.42
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #564 To Sprulock 69Kv Ln - TTX - EGSI - 77414R	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	4	8,458.66
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #564 To Sprulock 69Kv Ln - TTX - EGSI - 77414R	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	4	38,064.02
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #564 To Sprulock 69Kv Ln - TTX - EGSI - 77414R	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	24	14,802.68
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Navasota To Caldwell Industria - TTX - EGSI - 77060	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	267.03
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Navasota To Caldwell Industria - TTX - EGSI - 77060	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	125.06
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Navasota To Caldwell Industria - TTX - EGSI - 77060	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	2	5,760.53
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Navasota To Caldwell Industria - TTX - EGSI - 77060	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	32.20
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches To Mobil Chem #2 69Kv L - TTX - EGSI - 77562	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	1	447.36
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Neches To Mobil Chem #2 69Kv L - TTX - EGSI - 77562	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	3	156.57
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Div Ln To Nelson (Tx - TTX - EGSI - 74295	Transmission Plant	3550 Poles & Fxtrs -Trans	Crossarm - Conductor (All Sizes/Typ	Addition	200712	43	103,633.81
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Div Ln To Nelson (Tx - TTX - EGSI - 74295	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Polymer Suspension: P	Addition	200712	129	60,514.17
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Lake Charles Divisio - TTX - EGSI - 74296	Transmission Plant	3550 Poles & Fxtrs -Trans	Crossarm - Conductor (All Sizes/Typ	Addition	200712	43	91,067.35
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Orange To Lake Charles Divisio - TTX - EGSI - 74296	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Polymer Suspension: P	Addition	200712	129	56,655.78
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Port Acres Bulk To Gulf Oil 69 - TTX - EGSI - 77473	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	4	74,292.61
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Port Acres Bulk To Gulf Oil 69 - TTX - EGSI - 77473	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	3	76,769.03
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Port Acres Bulk To Gulf Oil 69 - TTX - EGSI - 77473	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	4,151.39
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Port Acres Bulk To Gulf Oil 69 - TTX - EGSI - 77473	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	21	45,602.37
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Port Acres Bulk To Gulf Oil 69 - TTX - EGSI - 77473	Transmission Plant	3561 Overhd Cond & Devices	Shieldwire - (All Sizes/Types): Al	Addition	200710	600	8,758.10
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Port Neches Bulk To Goodrich 6 - TTX - EGSI - 77427	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	7	109,015.89
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Port Neches Bulk To Goodrich 6 - TTX - EGSI - 77427	Transmission Plant	3561 Overhd Cond & Devices	Air Break Switch (All Kv Sizes): A	Addition	200710	3	16,475.95
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Port Neches Bulk To Goodrich 6 - TTX - EGSI - 77427	Transmission Plant	3561 Overhd Cond & Devices	Conductor (All Sizes): All Types,	Addition	200710	1200	1,977.11
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Port Neches Bulk To Goodrich 6 - TTX - EGSI - 77427	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	21	23,066.33
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Port Neches To Magnolia 69Kv L - TTX - EGSI - 77806	Transmission Plant	3550 Poles & Fxtrs -Trans	Guy Wire: TL:Guy Wire	Addition	200710	250	4,846.83
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Port Neches To Magnolia 69Kv L - TTX - EGSI - 77806	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	1	17,096.58
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Port Neches To Magnolia 69Kv L - TTX - EGSI - 77806	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	1	28,416.70
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Port Neches To Magnolia 69Kv L - TTX - EGSI - 77806	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	6	12,315.71
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Raywood To Dayton Bulk 69Kv Ln - TTX - EGSI - 77440	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	42,151.98
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Raywood To Dayton Bulk 69Kv Ln - TTX - EGSI - 77440	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	1,539.05
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Raywood To Dayton Bulk 69Kv Ln - TTX - EGSI - 77440	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	2	14,966.57
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Raywood To Dayton Bulk 69Kv Ln - TTX - EGSI - 77440	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	2	306,013.32
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Raywood To Dayton Bulk 69Kv Ln - TTX - EGSI - 77440	Transmission Plant	3561 Overhd Cond & Devices	Conductor (All Sizes): All Types,	Addition	200710	0	117,837.32
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Raywood To Dayton Bulk 69Kv Ln - TTX - EGSI - 77440	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200710	1800	2,886.41
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Raywood-City Of Liberty (Natio - TTX - EGSI - 74542	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	133,840.65
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Raywood-City Of Liberty (Natio - TTX - EGSI - 74542	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	38,578.30
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine To Div Line To China 23 - TTX - EGSI - 72496	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	3,717.13
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Sabine-Dic Ln-Port Neches Bulk - TTX - EGSI - 74516	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	(31,117.68)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	So Beaumont To Colonial Hebert - TTX - EGSI - 77114	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	(66,447.39)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	So Beaumont To Colonial Hebert - TTX - EGSI - 77114	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	(9,826.87)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	So Beaumont To Colonial Hebert - TTX - EGSI - 77114	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	2,692.99
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	So Beaumont To Colonial Hebert - TTX - EGSI - 77114	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	(155,589.17)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	So Beaumont To Colonial Hebert - TTX - EGSI - 77114	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	(23,010.01)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	So Beaumont To Colonial Hebert - TTX - EGSI - 77114	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	6,305.73
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Lincoln 69Kv - TTX - EGSI - 77576	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	18,151.64
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Lincoln 69Kv - TTX - EGSI - 77576	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	(9,189.46)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Lincoln 69Kv - TTX - EGSI - 77576	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	2,664.25
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Lincoln 69Kv - TTX - EGSI - 77576	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	1	4,601.32
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Lincoln 69Kv - TTX - EGSI - 77576	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	1	9,351.75
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Lincoln 69Kv - TTX - EGSI - 77576	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	6	3,220.92
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	West End To Amelia Bulk 69Kv L - TTX - EGSI - 77456	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	7	80,021.08
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	West End To Amelia Bulk 69Kv L - TTX - EGSI - 77456	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	7	364,733.83
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	West End To Amelia Bulk 69Kv L - TTX - EGSI - 77456	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	42	48,708.52
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	West End To Goodyear Cheek 69K - TTX - EGSI - 77466	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	18	82,495.59
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	West End To Goodyear Cheek 69K - TTX - EGSI - 77466	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	19	150,325.32
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	West End To Goodyear Cheek 69K - TTX - EGSI - 77466	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	111	58,892.70
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #473 To Line #484 69Kv Ln - TTX - EGSI - 77564A	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	(151,050.17)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #473 To Line #484 69Kv Ln - TTX - EGSI - 77564A	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	(26,785.91)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #473 To Line #484 69Kv Ln - TTX - EGSI - 77564A	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	13,466.68
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #473 To Line #484 69Kv Ln - TTX - EGSI - 77564A	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	(79,141.75)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #473 To Line #484 69Kv Ln - TTX - EGSI - 77564A	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	(14,034.31)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #473 To Line #484 69Kv Ln - TTX - EGSI - 77564A	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	7,055.78
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #62 To Bayou Fannett 69Kv - TTX - EGSI - 77185R	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	(10,014.87)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #62 To Bayou Fannett 69Kv - TTX - EGSI - 77185R	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	(9,693.91)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #62 To Bayou Fannett 69Kv - TTX - EGSI - 77185R	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	1,452.41
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #62 To Bayou Fannett 69Kv - TTX - EGSI - 77185R	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	(5,877.14)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #62 To Bayou Fannett 69Kv - TTX - EGSI - 77185R	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	(5,688.78)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #62 To Bayou Fannett 69Kv - TTX - EGSI - 77185R	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	852.32
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #81 To Kirbyville 69Kv Ln - TTX - EGSI - 77409R	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	2	13,898.25
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #81 To Kirbyville 69Kv Ln - TTX - EGSI - 77409R	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Steel (All Sizes): Steel:	Addition	200710	2	229,817.27
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #81 To Kirbyville 69Kv Ln - TTX - EGSI - 77409R	Transmission Plant	3561 Overhd Cond & Devices	Conductor - (All Sizes/Types): All	Addition	200710	3600	5,360.75
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #81 To Kirbyville 69Kv Ln - TTX - EGSI - 77409R	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	12	263,285.18
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #89 To Blue Water 69Kv Ln - TTX - EGSI - 77175R	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	1	(647,423.21)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #89 To Blue Water 69Kv Ln - TTX - EGSI - 77175R	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	1	392,546.95
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #89 To Blue Water 69Kv Ln - TTX - EGSI - 77175R	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	1	(336,792.98)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #89 To Blue Water 69Kv Ln - TTX - EGSI - 77175R	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	1	(600,262.85)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #89 To Blue Water 69Kv Ln - TTX - EGSI - 77175R	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	1	363,952.58
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	Line #89 To Blue Water 69Kv Ln - TTX - EGSI - 77175R	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	1	(312,259.93)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Winshire 69K - TTX - EGSI - 77062R	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200710	4	(115,147.44)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Winshire 69K - TTX - EGSI - 77062R	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200711	4	(70,931.25)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Winshire 69K - TTX - EGSI - 77062R	Transmission Plant	3550 Poles & Fxtrs -Trans	Non-Unitized	Addition	200712	3	139,157.73
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Winshire 69K - TTX - EGSI - 77062R	Transmission Plant	3550 Poles & Fxtrs -Trans	X-Braces: TL:X-Braces	Addition	200710	2	657.67
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Winshire 69K - TTX - EGSI - 77062R	Transmission Plant	3550 Poles & Fxtrs -Trans	Poles, Concrete (All Sizes): Concr	Addition	200710	6	49,840.49
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Winshire 69K - TTX - EGSI - 77062R	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200710	5	27,832.22
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Winshire 69K - TTX - EGSI - 77062R	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200711	5	(17,978.96)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Winshire 69K - TTX - EGSI - 77062R	Transmission Plant	3561 Overhd Cond & Devices	Non-Unitized	Addition	200712	4	61,785.79
TX000: ENTERGY TEXAS, INC.	TX	Transmission Line-EGSI-TX	South Beaumont To Winshire 69K - TTX - EGSI - 77062R	Transmission Plant	3561 Overhd Cond & Devices	Insulators - Braced Post: Braced P	Addition	200710	21	7,124.78
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Pee Dee - TST - EGSI - 23090	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200710	1	620.98
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Pee Dee - TST - EGSI - 23090	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	33.53
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Rivtrin - TST - EGSI - 23089	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	5,555.17
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Rivtrin - TST - EGSI - 23089	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	284.02
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Rivtrin - TST - EGSI - 23089	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200711	1	14,263.27
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Rivtrin - TST - EGSI - 23089	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	729.24
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	West End - TST - EGSI - 21122	Distribution Plant	3620 Stn Equip-Dist	Fuse Equipment: High Voltage Fuses:	Addition	200712	2	2,865.15
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	West End - TST - EGSI - 21122	Distribution Plant	3620 Stn Equip-Dist	Transformer Oil Cooling Devices: A	Addition	200712	10	3,370.75
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Metro Sub - TST - EGSI - 23174	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	10,328.10
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	New Caney - TST - EGSI - 23104	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	3,604.85
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cypress Sub - TST - EGSI - 21210	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200710	1	21,081.71
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cypress Sub - TST - EGSI - 21210	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	(11,459.64)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cypress Sub - TST - EGSI - 21210	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	23,561.93
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cypress Sub - TST - EGSI - 21210	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200711	1	(12,807.82)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Lewis Creek - TST - EGSI - 23105	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200711	1	45,251.64
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Lewis Creek - TST - EGSI - 23105	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	378.51
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	McLewis Sub - TST - EGSI - 31710	Distribution Plant	3620 Stn Equip-Dist	Bushings, Transformers: Transforme	Addition	200710	4	13,702.56
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cow Substation - TST - EGSI - 21155	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	162,231.58
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cow Substation - TST - EGSI - 21155	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200711	1	56,439.74
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cow Substation - TST - EGSI - 21155	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	3,774.97
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cow Substation - TST - EGSI - 21155	Transmission Plant	3520 Structure & Improvements	Non-Unitized	Addition	200710	1	3,949.18
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cow Substation - TST - EGSI - 21155	Transmission Plant	3520 Structure & Improvements	Non-Unitized	Addition	200711	1	1,373.90
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cow Substation - TST - EGSI - 21155	Transmission Plant	3520 Structure & Improvements	Non-Unitized	Addition	200712	1	91.90
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Echo Substation - TST - EGSI - 21130	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	2	28,417.18
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Echo Substation - TST - EGSI - 21130	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	(10,825.64)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	April Substation - TST - EGSI - 33145	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	1,662.26
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Bragg Substation - TST - EGSI - 31083	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	11,128.15
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Bragg Substation - TST - EGSI - 31083	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	11,136.80
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Bryan Substation - TST - EGSI - 23156	Distribution Plant	3620 Stn Equip-Dist	Arrester : 13.8Kv System, 13.8Kv Sy	Addition	200712	12	447.47
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Bryan Substation - TST - EGSI - 23156	Transmission Plant	3530 Stn Eqpt-Trans	Arrester : 69Kv System & Below	Addition	200712	12	894.94
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Bryan Substation - TST - EGSI - 23156	Transmission Plant	3530 Stn Eqpt-Trans	Arrester : 138Kv System, 138Kv Syst	Addition	200712	12	1,576.35
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cabot Substation - TST - EGSI - 31064	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	17,203.17
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cedar Substation - TST - EGSI - 33114	Distribution Plant	3620 Stn Equip-Dist	Arrester : 13.8Kv System, 13.8Kv Sy	Addition	200712	0	8,834.47
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cedar Substation - TST - EGSI - 33114	Distribution Plant	3620 Stn Equip-Dist	Dist.Sub - Arrester : 138Kv System,	Addition	200712	3	8,723.22
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cheek Substation - TST - EGSI - 31171	Distribution Plant	3620 Stn Equip-Dist	Sw, Hookstk 1 Pole Disconnect: 13.8	Addition	200712	6	2,177.14
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cheek Substation - TST - EGSI - 31171	Distribution Plant	3620 Stn Equip-Dist	Transformer Oil Cooling Devices: A	Addition	200712	2	1,494.13
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	32,859.42
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	1,008.82
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Distribution Plant	3620 Stn Equip-Dist	Reactor: All Voltages: DS:Reactor	Addition	200712	0	(6.04)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Arrester : 138Kv System, 138Kv Syst	Addition	200712	0	(0.70)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Bus Insulator Assembly, Rigid: 230K	Addition	200712	0	(6.10)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Cable, Control For Below 230 Kv: F	Addition	200712	0	(2.82)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Circuit Breakers : 230Kv System, 23	Addition	200712	0	(52.56)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Conduit, Duct Or Cable Trench: Duc	Addition	200712	0	(3.90)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Coupling Capacitor For 230 Kv & Abo	Addition	200712	0	(5.12)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Dc Power Converter: Dc Power: TS:	Addition	200712	0	(0.30)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Digital Channel Shelf Including She	Addition	200712	0	(1.12)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Feedlines Including Waveguide, Heli	Addition	200712	0	(0.02)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Fiber Optic Transmitter/Receiver:	Addition	200712	0	(3.48)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Foundation For 230 Kv & Above: For	Addition	200712	0	(21.61)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Grounding System: TS:Grounding Sys	Addition	200712	0	(1.20)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Line Relaying For 230 Kv & Above:	Addition	200712	0	(4.84)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Line Relaying For Below 230 Kv: Fo	Addition	200712	0	(4.98)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Panel, Differential Relayfor 230 Kv	Addition	200712	0	(2.22)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Panel, Line Relay For Below 230 Kv:	Addition	200712	0	(3.46)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Panel, Metering (Station) For Below	Addition	200712	0	(1.08)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Panel, Power-Ac/Dc: Power-Ac/Dc:	Addition	200712	0	(1.40)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Panel, Relay And/Or Control For 230	Addition	200712	0	(5.52)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Panel, Relay And/Or Control For Bel	Addition	200712	0	(2.52)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Rigid Bus & Power Wiring (Station)	Addition	200712	0	(5.82)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Structural Steel/Alum: Box Truss St	Addition	200712	0	(1.22)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Structural Steel/Alum: Bus Support	Addition	200712	0	(2.16)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Structural Steel/Alum: Stand For 23	Addition	200712	0	(0.78)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Structural Steel/Alum: Tower For 23	Addition	200712	0	(3.20)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Switch, Air Break 3 Pole: 230Kv Sys	Addition	200712	0	(6.44)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Switch, Grounding 3 Pole: For 230K	Addition	200712	0	(4.04)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3530 Stn Eqpt-Trans	Transformer, Instrument: Potential	Addition	200712	0	(0.48)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	China Substation - TST - EGSI - 21164	Transmission Plant	3520 Structure & Improvements	Site Preparation & Development: TS	Addition	200712	0	(3.84)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Federal 69Kv Sub - TST - EGSI - 21277	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	22.98
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Federal 69Kv Sub - TST - EGSI - 21277	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	505.20
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Front Substation - TST - EGSI - 21114	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	2,601.03
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Goree Substation - TST - EGSI - 33121	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200710	1	1,527.20
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Goree Substation - TST - EGSI - 33121	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	147.20
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Goree Substation - TST - EGSI - 33121	Distribution Plant	3620 Stn Equip-Dist	Telemetering Equipment: All Voltag	Addition	200712	3	3,600.93
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Jirou Substation - TST - EGSI - 21126	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	796.51
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Jirou Substation - TST - EGSI - 21126	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	315.28
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Jirou Substation - TST - EGSI - 21126	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	232.54
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Kolbs Substation - TST - EGSI - 22035	Transmission Plant	3530 Stn Eqpt-Trans	Bushings, Breaker Below 230Kv: Bre	Addition	200712	12	21,999.22
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Mclewis 69Kv Sub - TST - EGSI - 31223	Transmission Plant	3530 Stn Eqpt-Trans	Battery Set: Set: TS:Battery	Addition	200712	1	6,712.75
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Mclewis 69Kv Sub - TST - EGSI - 31223	Transmission Plant	3530 Stn Eqpt-Trans	Battery Rack/Enclosure: TS:Battery	Addition	200712	1	471.06
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Oilla Substation - TST - EGSI - 31267	Distribution Plant	3620 Stn Equip-Dist	Animal Protection Devices: DS:Anim	Addition	200712	1	7,130.11
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Conair Substation - TST - EGSI - 33005	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200710	1	2,266.56
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Conair Substation - TST - EGSI - 33005	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	13,695.49
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Grimes Substation - TST - EGSI - 23166	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	2	59,311.62
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Grimes Substation - TST - EGSI - 23166	Transmission Plant	3530 Stn Eqpt-Trans	Battery Set: Set: TS:Battery	Addition	200711	1	45,533.99
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Grimes Substation - TST - EGSI - 23166	Transmission Plant	3530 Stn Eqpt-Trans	Battery Charger: TS:Battery Charge	Addition	200711	1	8,403.63
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Grimes Substation - TST - EGSI - 23166	Transmission Plant	3530 Stn Eqpt-Trans	Battery Rack/Enclosure: TS:Battery	Addition	200711	1	4,287.57
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Grimes Substation - TST - EGSI - 23166	Transmission Plant	3530 Stn Eqpt-Trans	Reactor For Below 230 Kv: For Belo	Addition	200710	3	209,328.68
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Hardin Substation - TST - EGSI - 31197	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	33,602.14
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Hardin Substation - TST - EGSI - 31197	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200711	1	306.14
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Hearne Substation - TST - EGSI - 23086	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	1,941.01
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Helbig Substation - TST - EGSI - 21136	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	4,790.42
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Helbig Substation - TST - EGSI - 21136	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	28,790.53
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Hickory Ridge Sub - TST - EGSI - 33188	Distribution Plant	3620 Stn Equip-Dist	Animal Protection Devices: DS:Anim	Addition	200711	1	3,393.00
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Jasper Substation - TST - EGSI - 21036	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	8,554.79
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Mayhaw Substation - TST - EGSI - 31165	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200710	1	440.29
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Mayhaw Substation - TST - EGSI - 31165	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	239.15
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Mayhaw Substation - TST - EGSI - 31165	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	1,190.51
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Mayhaw Substation - TST - EGSI - 31165	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	646.64
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Mchale Substation - TST - EGSI - 31027	Distribution Plant	3620 Stn Equip-Dist	Arrester : 13.8Kv System, 13.8Kv Sy	Addition	200712	3	838.37
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Mchale Substation - TST - EGSI - 31027	Transmission Plant	3530 Stn Eqpt-Trans	Arrester : 69Kv System & Below	Addition	200712	3	1,676.75
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Neches Substation - TST - EGSI - 21113	Distribution Plant	3620 Stn Equip-Dist	Transformer, Instrument: Potential,	Addition	200712	3	12,710.64
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Neches Substation - TST - EGSI - 21113	Transmission Plant	3530 Stn Eqpt-Trans	Battery Charger: TS:Battery Charge	Addition	200712	1	4,119.18
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Neches Substation - TST - EGSI - 21113	Transmission Plant	3530 Stn Eqpt-Trans	Cable, Control For Below 230 Kv: F	Addition	200712	0	(12.49)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Neches Substation - TST - EGSI - 21113	Transmission Plant	3530 Stn Eqpt-Trans	Panel, Line Relay For Below 230 Kv:	Addition	200712	0	(27.52)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Neches Substation - TST - EGSI - 21113	Transmission Plant	3530 Stn Eqpt-Trans	Panel, Relay And/Or Control For Bel	Addition	200712	0	(21.56)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Orange Substation - TST - EGSI - 21132	Distribution Plant	3620 Stn Equip-Dist	Circuit Breakers : 13.8Kv, Up To 34	Addition	200712	1	13,582.55
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Orange Substation - TST - EGSI - 21132	Distribution Plant	3620 Stn Equip-Dist	Dist.Sub - Switch, Air Break 3 Pole	Addition	200712	1	3,492.64
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Orange Substation - TST - EGSI - 21132	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200711	1	480,620.25
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Orange Substation - TST - EGSI - 21132	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	13,636.71
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Orange Substation - TST - EGSI - 21132	Transmission Plant	3530 Stn Eqpt-Trans	Transformer Oil Cooling Devices Bel	Addition	200712	3	863.48
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Orange Substation - TST - EGSI - 21132	Transmission Plant	3520 Structure & Improvements	Non-Unitized	Addition	200711	1	8,489.98
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Orange Substation - TST - EGSI - 21132	Transmission Plant	3520 Structure & Improvements	Non-Unitized	Addition	200712	1	240.88
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Porter Substation - TST - EGSI - 23142	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	658.28
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Sabine Substation - TST - EGSI - 22143	Transmission Plant	3530 Stn Eqpt-Trans	Circuit Breakers : 230Kv System, 23	Addition	200712	0	187,090.61
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Tamina Substation - TST - EGSI - 33070	Transmission Plant	3530 Stn Eqpt-Trans	Bus Insulator Assembly, Rigid: 138K	Addition	200712	0	(5.69)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Tamina Substation - TST - EGSI - 33070	Transmission Plant	3530 Stn Eqpt-Trans	Cable, Control For Below 230 Kv: F	Addition	200712	0	(27.51)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Tamina Substation - TST - EGSI - 33070	Transmission Plant	3530 Stn Eqpt-Trans	Circuit Breakers : 138Kv System, 13	Addition	200712	0	(107.96)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Tamina Substation - TST - EGSI - 33070	Transmission Plant	3530 Stn Eqpt-Trans	Conduit, Duct Or Cable Trench: Duc	Addition	200712	0	(3.80)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Tamina Substation - TST - EGSI - 33070	Transmission Plant	3530 Stn Eqpt-Trans	Dc Power Converter: Dc Power: TS:	Addition	200712	0	(8.58)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Tamina Substation - TST - EGSI - 33070	Transmission Plant	3530 Stn Eqpt-Trans	Digital Channel Shelf Including She	Addition	200712	0	(9.74)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Tamina Substation - TST - EGSI - 33070	Transmission Plant	3530 Stn Eqpt-Trans	Digital Channel: TS:Digital Channe	Addition	200712	0	(24.41)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Tamina Substation - TST - EGSI - 33070	Transmission Plant	3530 Stn Eqpt-Trans	Feedlines Including Waveguide, Heli	Addition	200712	0	(0.75)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Tamina Substation - TST - EGSI - 33070	Transmission Plant	3530 Stn Eqpt-Trans	Fiber Optic Termination Equipment:	Addition	200712	0	(13.75)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Tamina Substation - TST - EGSI - 33070	Transmission Plant	3530 Stn Eqpt-Trans	Fiber Optic Transmitter/Receiver:	Addition	200712	0	(26.29)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Tamina Substation - TST - EGSI - 33070	Transmission Plant	3530 Stn Eqpt-Trans	Grounding System: TS:Grounding Sys	Addition	200712	0	(21.88)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Tamina Substation - TST - EGSI - 33070	Transmission Plant	3530 Stn Eqpt-Trans	Panel, Relay And/Or Control For Bel	Addition	200712	0	(37.17)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Tamina Substation - TST - EGSI - 33070	Transmission Plant	3530 Stn Eqpt-Trans	Reactor For Below 230 Kv: For Belo	Addition	200712	0	(22.96)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Tamina Substation - TST - EGSI - 33070	Transmission Plant	3530 Stn Eqpt-Trans	Rigid Bus & Power Wiring (Station)	Addition	200712	0	(6.07)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Tamina Substation - TST - EGSI - 33070	Transmission Plant	3530 Stn Eqpt-Trans	Structural Steel/Alum: Bus Support	Addition	200712	0	(1.58)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Tamina Substation - TST - EGSI - 33070	Transmission Plant	3530 Stn Eqpt-Trans	Structural Steel/Alum: Stand For 23	Addition	200712	0	(2.99)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Tamina Substation - TST - EGSI - 33070	Transmission Plant	3530 Stn Eqpt-Trans	Switch, Grounding 3 Pole: For 138K	Addition	200712	0	(8.55)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Travis Substation - TST - EGSI - 21115	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	470.00
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Walden Substation - TST - EGSI - 33132	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	3,257.11
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Walden Substation - TST - EGSI - 33132	Distribution Plant	3620 Stn Equip-Dist	Transformer Oil Cooling Devices: A	Addition	200712	2	2,725.19
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Warren Substation - TST - EGSI - 31191	Distribution Plant	3620 Stn Equip-Dist	Battery Set: Set: DS:Battery	Addition	200712	1	10,093.06
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Warren Substation - TST - EGSI - 31191	Distribution Plant	3620 Stn Equip-Dist	Battery Charger: DS:Battery Charge	Addition	200712	1	4,485.80
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Warren Substation - TST - EGSI - 31191	Distribution Plant	3620 Stn Equip-Dist	Battery Rack/Enclosure: DS:Battery	Addition	200712	1	1,682.17
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Warren Substation - TST - EGSI - 31191	Distribution Plant	3620 Stn Equip-Dist	Switch Motor Mechanism: All Voltag	Addition	200712	1	14,018.16
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Wyntex Substation - TST - EGSI - 33106	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	20,091.23
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Wyntex Substation - TST - EGSI - 33106	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200711	1	511.15
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Wyntex Substation - TST - EGSI - 33106	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	1,273.40
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Calvert Substation - TST - EGSI - 33099	Distribution Plant	3620 Stn Equip-Dist	Arrester : 13.8Kv System, 13.8Kv Sy	Addition	200712	0	4,331.11
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Calvert Substation - TST - EGSI - 33099	Distribution Plant	3620 Stn Equip-Dist	Arrester : 34.5Kv System, 34.5Kv Sy	Addition	200712	12	4,061.26
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Calvert Substation - TST - EGSI - 33099	Distribution Plant	3620 Stn Equip-Dist	Dist.Sub - Switch, Air Break 3 Pole	Addition	200712	1	20,023.14
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Calvert Substation - TST - EGSI - 33099	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	52,063.75
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Calvert Substation - TST - EGSI - 33099	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200711	1	1,929.04
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Calvert Substation - TST - EGSI - 33099	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	930.76
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Calvert Substation - TST - EGSI - 33099	Transmission Plant	3530 Stn Eqpt-Trans	Arrester : 69Kv System & Below	Addition	200712	12	6,368.47
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cordrey Substation - TST - EGSI - 31021	Distribution Plant	3620 Stn Equip-Dist	Grounding System: DS:Grounding Sys	Addition	200710	150	8,137.24
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Craigen Substation - TST - EGSI - 31255	Distribution Plant	3620 Stn Equip-Dist	Fuse Equipment: High Voltage Fuses:	Addition	200712	3	6,107.62
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Craigen Substation - TST - EGSI - 31255	Distribution Plant	3620 Stn Equip-Dist	Transformer, Power: Power: DS:Tra	Addition	200712	1	17,450.35
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Crystal Substation - TST - EGSI - 33138	Distribution Plant	3620 Stn Equip-Dist	Circuit Breakers : 34.5Kv, Up To 69	Addition	200711	1	46,617.17
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Evadale Substation - TST - EGSI - 21142	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	93.49
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Evadale Substation - TST - EGSI - 21142	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	1,406.57
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Jeffcon Substation - TST - EGSI - 33017	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	5,634.37
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Jeffcon Substation - TST - EGSI - 33017	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	415.70
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Rye Mtr Substation - TST - EGSI - 33161	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	303.64
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Silsbee Substation - TST - EGSI - 31031	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200710	1	4,319.83
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Silsbee Substation - TST - EGSI - 31031	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	352.34
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Unclassified-Texas - TST - EGSI - 20000	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	7,054.47
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Unclassified-Texas - TST - EGSI - 20000	Transmission Plant	3530 Stn Eqpt-Trans	Bushings, Breaker Below 230Kv: Bre	Addition	200712	1	5,251.22
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Winfree Substation - TST - EGSI - 31039	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200710	1	24,534.31
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Eastgate Substation - TST - EGSI - 31075	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	8,270.64
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Goodrich Substation - TST - EGSI - 22036	Transmission Plant	3530 Stn Eqpt-Trans	Circuit Breakers : 69Kv System, 69K	Addition	200710	1	83,038.36
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Hankamer Substation - TST - EGSI - 31148	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	10,462.54
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Hartburg Substation - TST - EGSI - 21167	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	2	35,802.19
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Hartburg Substation - TST - EGSI - 21167	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200711	2	2,880.10
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Hartburg Substation - TST - EGSI - 21167	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	2	20,310.73
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Kickapoo Substation - TST - EGSI - 33136	Distribution Plant	3620 Stn Equip-Dist	Animal Protection Devices: DS:Anim	Addition	200711	1	3,562.65
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Mcdonald Substation - TST - EGSI - 31218	Distribution Plant	3620 Stn Equip-Dist	Rtu (Supervisory & Other): DS:Rtu	Addition	200711	1	55,889.83
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Navasota Substation - TST - EGSI - 23082	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	2,540.01
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Navasota Substation - TST - EGSI - 23082	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	35.57
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Parkdale Substation - TST - EGSI - 21186	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200711	1	17,911.48
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Parkdale Substation - TST - EGSI - 21186	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	1,561.50
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Pennwalt Substation - TST - EGSI - 31213	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	1,545.36
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Pennwalt Substation - TST - EGSI - 31213	Distribution Plant	3620 Stn Equip-Dist	Contact Assembly, LTC.: Unclassifi	Addition	200711	1	23,292.11
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Saratoga Substation - TST - EGSI - 31162	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	9,559.04
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Speedway Substation - TST - EGSI - 33113	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200710	1	7,447.34
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Speedway Substation - TST - EGSI - 33113	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	4.06
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Speedway Substation - TST - EGSI - 33113	Distribution Plant	3620 Stn Equip-Dist	Animal Protection Devices: DS:Anim	Addition	200711	1	3,621.38
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Winshire Substation - TST - EGSI - 21014	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	13,478.34
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Winshire Substation - TST - EGSI - 21014	Distribution Plant	3620 Stn Equip-Dist	Battery Rack/Enclosure: DS:Battery	Addition	200711	1	2,193.73
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Alden 138/34.5Kv Sub - TST - EGSI - 23196	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	15,293.82
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cedar Hill 138Kv Sub - TST - EGSI - 31288	Distribution Plant	3620 Stn Equip-Dist	Animal Protection Devices: DS:Anim	Addition	200711	1	3,588.75
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cleveland Substation - TST - EGSI - 23080	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200710	2	25,217.14
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Cleveland Substation - TST - EGSI - 23080	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	2	8,064.91
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Douchette Substation - TST - EGSI - 21124	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	2	17,651.27
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Douchette Substation - TST - EGSI - 21124	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200711	1	2,274.91
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Elizabeth Substation - TST - EGSI - 21138	Transmission Plant	3530 Stn Eqpt-Trans	Carrier Sets/Equipment For Below 23	Addition	200711	1	20,712.46
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	North End Substation - TST - EGSI - 21118	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200710	1	49.04
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	North End Substation - TST - EGSI - 21118	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	293.35
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	North End Substation - TST - EGSI - 21118	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	2	2,857.28
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	North End Substation - TST - EGSI - 21118	Distribution Plant	3620 Stn Equip-Dist	Cable, Control: DS:Cable, Control	Addition	200710	100	4,834.28
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	North End Substation - TST - EGSI - 21118	Distribution Plant	3620 Stn Equip-Dist	Circuit Breakers : 34.5Kv, Up To 69	Addition	200710	2	74,125.88
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	North End Substation - TST - EGSI - 21118	Distribution Plant	3620 Stn Equip-Dist	Conduit, Duct Or Cable Trench: Duc	Addition	200710	100	3,369.36
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	North End Substation - TST - EGSI - 21118	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	214.37
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	North End Substation - TST - EGSI - 21118	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	2	12,047.22
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Oak Ridge Substation - TST - EGSI - 23109	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	2,422.10
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Oak Ridge Substation - TST - EGSI - 23109	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	13.47
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Oak Ridge Substation - TST - EGSI - 23109	Transmission Plant	3530 Stn Eqpt-Trans	Capacitors (Single) Below 230Kv: (	Addition	200710	15	43,791.54
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Sour Lake Substation - TST - EGSI - 31127	Transmission Plant	3530 Stn Eqpt-Trans	Line Relaying For Below 230 Kv: Fo	Addition	200712	0	66.13
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Splendora Substation - TST - EGSI - 33120	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200711	1	38,617.75
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Splendora Substation - TST - EGSI - 33120	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	8,635.87
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Blue Water Substation - TST - EGSI - 31066	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	8,840.51
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Blue Water Substation - TST - EGSI - 31066	Distribution Plant	3620 Stn Equip-Dist	Dist.Sub - Bus Insulator Assembly,	Addition	200711	6	3,174.54
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Blue Water Substation - TST - EGSI - 31066	Transmission Plant	3530 Stn Eqpt-Trans	Rigid Bus & Power Wiring (Station)	Addition	200711	200	2,389.41
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Blue Water Substation - TST - EGSI - 31066	Transmission Plant	3530 Stn Eqpt-Trans	Switch, Air Break 3 Pole: 69Kv Syst	Addition	200711	1	21,095.17
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Briarcliff Substation - TST - EGSI - 31020	Distribution Plant	3620 Stn Equip-Dist	Contacts, Breaker: Unclassified:	Addition	200712	1	13,734.75
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Dupont Dee Substation - TST - EGSI - 22048	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	7,608.42
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Fort Worth Substation - TST - EGSI - 22038	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200710	1	(4,082.94)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Fort Worth Substation - TST - EGSI - 22038	Transmission Plant	3530 Stn Eqpt-Trans	Transformer, Instrument: Potential	Addition	200711	1	5,176.40
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Georgetown Substation - TST - EGSI - 21207	Distribution Plant	3620 Stn Equip-Dist	Battery Set: Set: DS:Battery	Addition	200712	1	6,147.93
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Georgetown Substation - TST - EGSI - 21207	Distribution Plant	3620 Stn Equip-Dist	Battery Charger: DS:Battery Charge	Addition	200712	1	2,912.19
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Georgetown Substation - TST - EGSI - 21207	Distribution Plant	3620 Stn Equip-Dist	Battery Rack/Enclosure: DS:Battery	Addition	200712	1	755.02
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Georgetown Substation - TST - EGSI - 21207	Transmission Plant	3530 Stn Eqpt-Trans	Switch, Air Break 3 Pole: 230Kv Sys	Addition	200712	1	64,715.21
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Huntsville Substation - TST - EGSI - 23083	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200710	1	8,055.22
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Huntsville Substation - TST - EGSI - 23083	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	200.05
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Manchester Substation - TST - EGSI - 32009	Distribution Plant	3620 Stn Equip-Dist	Arrester : 13.8Kv System, 13.8Kv Sy	Addition	200712	3	1,910.83
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Manchester Substation - TST - EGSI - 32009	Distribution Plant	3620 Stn Equip-Dist	Bus Insulator Assembly, Rigid: 13.8	Addition	200712	0	591.67
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Manchester Substation - TST - EGSI - 32009	Distribution Plant	3620 Stn Equip-Dist	Fuse Equipment: High Voltage Fuses:	Addition	200712	3	7,403.21
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Manchester Substation - TST - EGSI - 32009	Distribution Plant	3620 Stn Equip-Dist	Sw, Hookstk 1 Pole Disconnect: 13.8	Addition	200712	0	9,313.91
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Manchester Substation - TST - EGSI - 32009	Distribution Plant	3620 Stn Equip-Dist	Switch, Air Break 3 Pole: 13.8Kv, U	Addition	200712	0	1,281.97
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Substation - TST - EGSI - 32018	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	18,677.75
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Somerville Substation - TST - EGSI - 33028	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200710	1	28,500.18
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Somerville Substation - TST - EGSI - 33028	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	5,091.24
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Spindletop Substation - TST - EGSI - 31264	Transmission Plant	3530 Stn Eqpt-Trans	Contact Assembly, LTC. 230Kv & Abov	Addition	200712	1	16,555.28
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Amelia Bulk Substation - TST - EGSI - 21137	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200711	1	27,882.79
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Amelia Bulk Substation - TST - EGSI - 21137	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	173.55
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Amelia Bulk Substation - TST - EGSI - 21137	Transmission Plant	3530 Stn Eqpt-Trans	Line Relaying For 230 Kv & Above:	Addition	200711	1	44,943.72
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Bridge City Substation - TST - EGSI - 31058	Distribution Plant	3620 Stn Equip-Dist	Animal Protection Devices: DS:Anim	Addition	200712	1	13,527.23
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Conroe Bulk Substation - TST - EGSI - 23087	Distribution Plant	3620 Stn Equip-Dist	Transformer Oil Cooling Devices: A	Addition	200712	2	1,359.04
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Conroe Bulk Substation - TST - EGSI - 23087	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200711	1	44,720.31
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Conroe Bulk Substation - TST - EGSI - 23087	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	1,911.34
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Dayton Bulk Substation - TST - EGSI - 21123	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	152.53
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Toledo Bend Substation - TST - EGSI - 21154	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200711	1	4,770.50
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Houston Chem Substation - TST - EGSI - 31016	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	5,726.07
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Houston Chem Substation - TST - EGSI - 31016	Distribution Plant	3620 Stn Equip-Dist	Arrester : 13.8Kv System, 13.8Kv Sy	Addition	200710	6	2,266.41
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Houston Chem Substation - TST - EGSI - 31016	Distribution Plant	3620 Stn Equip-Dist	Bushings, Transformers: Transforme	Addition	200711	3	5,689.47
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Houston Chem Substation - TST - EGSI - 31016	Transmission Plant	3530 Stn Eqpt-Trans	Arrester : 69Kv System & Below	Addition	200710	6	6,110.68
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Lovells Lake Substation - TST - EGSI - 31023	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	20,220.13
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Lovells Lake Substation - TST - EGSI - 31023	Distribution Plant	3620 Stn Equip-Dist	Cable, Control: DS:Cable, Control	Addition	200712	50	258.98
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Lovells Lake Substation - TST - EGSI - 31023	Distribution Plant	3620 Stn Equip-Dist	Battery Test Switch: DS:Battery Te	Addition	200712	1	6,786.96
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Lovells Lake Substation - TST - EGSI - 31023	Distribution Plant	3620 Stn Equip-Dist	Fuse Equipment: High Voltage Fuses:	Addition	200711	4	6,766.72
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Lovells Lake Substation - TST - EGSI - 31023	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	(2,913.75)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Bauou Fannett Substation - TST - EGSI - 31041	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	7,277.78
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Lacon 138 / 13.8 Kva Sub - TST - EGSI - 23198	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	39,497.77
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Lacon 138 / 13.8 Kva Sub - TST - EGSI - 23198	Distribution Plant	3620 Stn Equip-Dist	Transformer Oil Cooling Devices: A	Addition	200712	2	1,359.04
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Magnolia Ames Substation - TST - EGSI - 31107	Distribution Plant	3620 Stn Equip-Dist	Arrester : 12Kv System & Below, 12K	Addition	200712	3	1,205.34
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Magnolia Ames Substation - TST - EGSI - 31107	Transmission Plant	3530 Stn Eqpt-Trans	Arrester : 138Kv System, 138Kv Syst	Addition	200712	3	5,149.67
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	North Silsbee Substation - TST - EGSI - 21140	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	81,733.07
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	North Silsbee Substation - TST - EGSI - 21140	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	330.37
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	North Silsbee Substation - TST - EGSI - 21140	Transmission Plant	3530 Stn Eqpt-Trans	Bus Insulator Assembly, Rigid: 69Kv	Addition	200711	24	25,575.38
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	North Silsbee Substation - TST - EGSI - 21140	Transmission Plant	3530 Stn Eqpt-Trans	Rigid Bus & Power Wiring (Station)	Addition	200711	200	4,792.32
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	North Silsbee Substation - TST - EGSI - 21140	Transmission Plant	3530 Stn Eqpt-Trans	Switch, Air Break 3 Pole: 69Kv Syst	Addition	200711	1	13,105.54
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Yankee Doodle Substation - TST - EGSI - 31116	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	33,628.08
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Yankee Doodle Substation - TST - EGSI - 31116	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	15,234.87
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Mclewis Sub 230-34.5/20Kv - TST - EGSI - 21224	Transmission Plant	3530 Stn Eqpt-Trans	Arrester : 230Kv System, 230Kv Syst	Addition	200712	3	3,533.06
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	South Beaumont Substation - TST - EGSI - 21131	Transmission Plant	3530 Stn Eqpt-Trans	Cable, Control For Below 230 Kv: F	Addition	200712	0	(189.33)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	South Beaumont Substation - TST - EGSI - 21131	Transmission Plant	3530 Stn Eqpt-Trans	Circuit Breakers : 138Kv System, 13	Addition	200712	0	(224.40)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	South Beaumont Substation - TST - EGSI - 21131	Transmission Plant	3530 Stn Eqpt-Trans	Conduit, Duct Or Cable Trench: Duc	Addition	200712	0	(9.40)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	South Beaumont Substation - TST - EGSI - 21131	Transmission Plant	3530 Stn Eqpt-Trans	Coupling Capacitive Voltage Transfo	Addition	200712	0	(157.32)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	South Beaumont Substation - TST - EGSI - 21131	Transmission Plant	3530 Stn Eqpt-Trans	Foundation For Below 230 Kv: For B	Addition	200712	0	(15.36)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	South Beaumont Substation - TST - EGSI - 21131	Transmission Plant	3530 Stn Eqpt-Trans	Grounding System: TS:Grounding Sys	Addition	200712	0	(3.02)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	South Beaumont Substation - TST - EGSI - 21131	Transmission Plant	3530 Stn Eqpt-Trans	Line Relaying For Below 230 Kv: Fo	Addition	200712	0	(22.58)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	South Beaumont Substation - TST - EGSI - 21131	Transmission Plant	3530 Stn Eqpt-Trans	Panel, Differential Relay For Below	Addition	200712	0	(26.18)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	South Beaumont Substation - TST - EGSI - 21131	Transmission Plant	3530 Stn Eqpt-Trans	Structural Steel/Alum: Stand For Be	Addition	200712	0	(26.00)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	South Beaumont Substation - TST - EGSI - 21131	Transmission Plant	3520 Structure & Improvements	Site Preparation & Development: TS	Addition	200712	0	(29.90)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Texas El Vista Substation - TST - EGSI - 32020	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200710	1	(21,456.70)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Texas El Vista Substation - TST - EGSI - 32020	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	(5,525.65)
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Colonial Hebert Substation - TST - EGSI - 31059	Distribution Plant	3620 Stn Equip-Dist	Arrester : 12Kv System & Below, 12K	Addition	200711	3	1,348.01
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Colonial Hebert Substation - TST - EGSI - 31059	Distribution Plant	3620 Stn Equip-Dist	Dist.Sub - Arrester : 69Kv System,	Addition	200711	3	4,043.98
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Magnolia Hebert Substation - TST - EGSI - 31091	Transmission Plant	3530 Stn Eqpt-Trans	Bus Insulator Assembly, Rigid: 69Kv	Addition	200712	12	7,200.97
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Magnolia Hebert Substation - TST - EGSI - 31091	Transmission Plant	3530 Stn Eqpt-Trans	Rtu (Supervisory & Other): TS:Rtu	Addition	200711	1	34,369.40
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Magnolia Hebert Substation - TST - EGSI - 31091	Transmission Plant	3530 Stn Eqpt-Trans	Switch, Air Break 3 Pole: (Unclassi	Addition	200712	0	4,500.61
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Magnolia Hebert Substation - TST - EGSI - 31091	Transmission Plant	3530 Stn Eqpt-Trans	Switch, Air Break 3 Pole: 69Kv Syst	Addition	200712	1	11,401.54
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	2,298.34
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200711	1	182.57
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	179.05
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Arrester : 230Kv System, 230Kv Syst	Addition	200710	18	0.32
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Battery Charger: TS:Battery Charge	Addition	200710	1	0.04
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Battery Rack/Enclosure: TS:Battery	Addition	200710	1	0.02
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Bus Insulator Assembly, Rigid: 230K	Addition	200710	333	1.12
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Cable, Control For 230 Kv & Above:	Addition	200710	80008	1.21
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Circuit Breakers : 230Kv System, 23	Addition	200710	8	4.35
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Conduit, Duct Or Cable Trench: Duc	Addition	200710	552	0.68
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Coupling Capacitive Voltage Transfo	Addition	200710	14	0.51
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Fiber Optic Cable Including Adss &	Addition	200710	3281	0.14
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Fiber Optic Termination Equipment:	Addition	200710	1	0.08
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Foundation For 230 Kv & Above: For	Addition	200710	167	3.12
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Grounding System: TS:Grounding Sys	Addition	200710	1500	0.74
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Lighting System, Yard: Yard: TS:L	Addition	200710	8	0.08
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Line Relaying For 230 Kv & Above:	Addition	200710	4	2.87
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Metering System (Station) For 230 K	Addition	200710	4	0.70
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Rigid Bus & Power Wiring (Station)	Addition	200710	6000	1.87
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Rtu (Supervisory & Other): TS:Rtu	Addition	200710	1	1.11
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Structural Steel/Alum: Box Truss St	Addition	200710	3	0.04
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Structural Steel/Alum: Bus Support	Addition	200710	39	0.66
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Structural Steel/Alum: Misc. For 23	Addition	200710	3	0.41
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Structural Steel/Alum: Switch Suppo	Addition	200710	14	0.37
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Structural Steel/Alum: Tower For 23	Addition	200710	4	1.52
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Switch, Air Break 3 Pole: 230Kv Sys	Addition	200710	22	1.64
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Switch, Grounding 3 Pole: For 230K	Addition	200710	6	0.73
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3530 Stn Eqpt-Trans	Transformer, Instrument: (Unclassif	Addition	200710	13	1.13
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3520 Structure & Improvements	Building (Control House): Control	Addition	200710	1	0.40
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3520 Structure & Improvements	Fence (Complete With Gates): TS:Fe	Addition	200710	0	0.15
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3520 Structure & Improvements	General Equipment: TS:General Equi	Addition	200710	1	0.14
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3520 Structure & Improvements	Heating/Cooling System: TS:Heating	Addition	200710	2	0.06
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3520 Structure & Improvements	Lighting System (Building): TS:Lig	Addition	200710	1	0.19
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Acres Bulk Substation - TST - EGSI - 22046	Transmission Plant	3520 Structure & Improvements	Site Preparation & Development: TS	Addition	200710	1	1.79
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Taylor Bayou Sub 69Kv/13.8 - TST - EGSI - 22278	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	15,410.29
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Taylor Bayou Sub 69Kv/13.8 - TST - EGSI - 22278	Transmission Plant	3520 Structure & Improvements	Non-Unitized	Addition	200711	1	241.53
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Taylor Bayou Sub 69Kv/13.8 - TST - EGSI - 22278	Transmission Plant	3520 Structure & Improvements	Non-Unitized	Addition	200712	1	7,080.69
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Port Neches Bulk Substation - TST - EGSI - 22043	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	163.64
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	West Orange 69Kv Substation - TST - EGSI - 21285	Distribution Plant	3620 Stn Equip-Dist	Animal Protection Devices: DS:Anim	Addition	200712	1	6,910.26
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Mabry Sub-Dist-69Kv-Cheek Tx - TST - EGSI - 31273	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200710	1	103.54
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Mabry Sub-Dist-69Kv-Cheek Tx - TST - EGSI - 31273	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200712	1	301.04
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Caldwell Industrial Substation - TST - EGSI - 33069	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200710	2	51,260.59
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Caldwell Industrial Substation - TST - EGSI - 33069	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200711	1	253.75
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Caldwell Industrial Substation - TST - EGSI - 33069	Distribution Plant	3620 Stn Equip-Dist	Non-Unitized	Addition	200712	1	6,736.20
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Caldwell Industrial Substation - TST - EGSI - 33069	Distribution Plant	3620 Stn Equip-Dist	Battery Set: Set: DS:Battery	Addition	200711	1	2,769.12
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Texas Substation Spare Locatio - TST - EGSI - 31001	Transmission Plant	3530 Stn Eqpt-Trans	Non-Unitized	Addition	200711	1	50,668.83
TX000: ENTERGY TEXAS, INC.	TX	Transmission Subs-EGSI-TX	Brazos Fish Creek Sub 138kv (Cust. Owned) - TST - EGSI - 33020	Transmission Plant	3530 Stn Eqpt-Trans	Metering System (Station) For Below	Addition	200712	1	6,122.32
										59,852,880.99

EX-10

ENTERGY CORPORATION SERVICE RECOGNITION PROGRAM
FOR NON-EMPLOYEE OUTSIDE DIRECTORS
(As Amended and Restated Effective January 1, 2009)
 

On October 29, 1999, the Board of Directors of Entergy Corporation approved, authorized, and adopted certain changes to this Entergy Corporation Service Recognition Program for Non-Employee Outside Directors (the "Program") that were incorporated into an amendment and restatement of the Program, which was effective January 1, 2000.

In December 2005, the Board of Directors of Entergy Corporation approved the adoption of Amendment No. 1 to the Program which provided payment elections with respect to all amounts deferred under this Program in accordance with Internal Revenue Service Notice 2005-1, Q&A-19(c) and related Proposed Treasury Regulations under Internal Revenue Code Section 409A.

The Program is hereby further amended and restated effective January 1, 2009 to implement changes required pursuant to and consistent with section 409A of the Internal Revenue Code ("Code") for amounts deferred on or after January 1, 2005. Amounts deferred prior to January 1, 2005 shall be administered under this Program as amended and restated, provided that, such amounts shall remain excluded from the requirements of, and potential adverse consequences associated with, section 409A to the extent permissible for amounts deferred on or before December 31, 2004.

Between January 1, 2005 and December 31, 2008 the Program has been operated in accordance with transition relief established by the Treasury Department and Internal Revenue Service under Code section 409A. This amendment and restatement is adopted in conformity with final regulations under section 409A issued by the Treasury Department on April 10, 2007 and effective January 1, 2009.

PURPOSE

The Program identifies those non-employee Outside Directors who are eligible for recognition for their service on the Entergy Corporation Board, sets forth the terms and conditions of the Program, and establishes the commencement date for receipt of benefits under the Program.

ARTICLE I

DEFINITIONS

The following terms shall have the meaning hereinafter indicated unless expressly provided herein to the contrary:

1. "Administrator" shall mean the Senior Vice-President, Human Resources and Administration for Entergy Services, Inc.
2. "Cause" shall mean:

1. a material violation by the Outside Director of any agreement with Entergy Corporation or the Entergy Corporation Board of Directors to which he is a party;

2. a material violation of the director relationship existing between the Outside Director and the Entergy Corporation Board of Directors at the time, including, without limitation, breach of confidentiality, moral turpitude, theft or defalcation; and

3. a material failure by the Outside Director to perform the services required by him by any agreement with Entergy Corporation or the Entergy Corporation Board of Directors to which he is a party, or, if there is no such agreement, a material failure by the Outside Director to perform the reasonable customary services of a director.

3. "Change in Control" shall mean:

1. the purchase or other acquisition by any person, entity or group of persons, acting in concert within the meaning of Sections 13(d) or 14(d) of the Securities Exchange Act of 1934 ("Act"), or any comparable successor provisions, of beneficial ownership (within the meaning of Rule 13d-3 promulgated under the Act) of twenty-five percent (25%) or more of either the shares of common stock outstanding immediately following such acquisition or the combined voting power of Entergy Corporation's voting securities entitled to vote generally and outstanding immediately following such acquisition, other than any such purchase or acquisition in connection with a Non-CIC Merger (defined in subsection (b) below);
2. the consummation of a merger or consolidation of Entergy Corporation, or any direct or indirect subsidiary of Entergy Corporation with any other corporation, other than a Non-CIC Merger, which shall mean a merger or consolidation immediately following which the individuals who compr ise the Board of Directors of Entergy Corporation immediately prior thereto constitute at least a majority of the Board of Directors of Entergy Corporation, or the board of directors of the entity surviving such merger or consolidation, or the board of directors of any parent thereof (unless the failure of such individuals to comprise at least such a majority is unrelated to such merger or consolidation);
3. the stockholders of Entergy Corporation approve a plan of complete liquidation or dissolution of Entergy Corporation or there is consummated an agreement for the sale or disposition by Entergy Corporation of all or substantially all of Entergy Corporation's assets; or
4. any change in the composition of the Board of Directors of Entergy Corporation such that during any period of two consecutive years, individuals who at the beginning of such period constitute the Board of Directors of Entergy Corporation and any new director (other than a director whose ini tial assumption of office is in connection with an actual or threatened election contest, including but not limited to a consent solicitation, relating to the election of directors of Entergy Corporation) whose appointment or election by the Board of Directors of Entergy Corporation or nomination for election by Entergy Corporation's stockholders was approved or recommended by a vote of at least two-thirds (2/3) of the directors then still in office who either were directors on the Effective Date or whose appointment, election or nomination for election was previously so approved or recommended, cease for any reason to constitute at least a majority thereof.

Provided, however, that no Change in Control shall be deemed to occur solely by virtue of (1) the insolvency or bankruptcy of Entergy Corporation; or (2) the transfer of assets of Entergy Corporation to an affiliate of Entergy Corporation, provided such affiliate assumes the obligations of the Program and agrees to continue uninterrupted the rights of the Participants under the Program; or (3) the consummation of any transaction or series of integrated transactions immediately following which the record holders of the common stock of Entergy Corporation immediately prior to such transaction or series of transactions continue to have substantially the same proportionate ownership in an entity which owns all or substantially all of the assets of Entergy Corporation immediately following such transaction or series of transactions.

4. "Change in Control Period" shall mean the period commencing on the date of a Potential Change in Control and ending twenty-four (24) calendar months following a Change in Control.

5. "Claims Administrator" shall mean the Administrator or its delegee responsible for administering claims for benefits under the Program.
6. "Claims Appeal Administrator" shall mean the Administrator or its delegee responsible for administering appeals from the denial or partial denial of claims for benefits under the Program.
7. "Disability" shall mean a physical or mental condition of an Outside Director, which, based on evidence satisfactory to the Administrator, and in the opinion of the Administrator, renders such Outside Director unfit to perform his duties as a director. Evidence may include medical evidence or that the Outside Director qualifies for disability benefits from Social Security Administration.
8. "Effective Date" shall mean January 1, 2009.
9. "Entergy Common Stock" shall mean Common Stock of Entergy Corporation, par value $.01 per share.
10. "Entergy Corporation Board" shall mean the Board of Directors of Entergy Corporation or its predecessor corporation.
11. "Equity Unit" shall mean the phantom market value equivalent of one (1) share of Entergy Common Stock. Equity Units do not represent actual shares of Entergy Common Stock and no shares of actual Entergy Common Stock are purchased or acquired under this Program.
12. "Key Employee" means one of the following (a) an officer of the Entergy Corporation having annual compensation greater than $145,000 (adjusted for inflation pursuant to section 416(i) of the Code and limited to the top 50 Employees), (b) a five percent owner of Entergy Corporation, or (c) a one percent owner of Entergy Corporation having annual c ompensation from Entergy Corporation of more than $150,000, subject to such other determinations made in the discretion of the Administrator, in a manner consistent with the regulations issued under section 409A of the Code.
13. "Outside Director" shall mean a non-employee outside director who: (a) becomes Separated from the Entergy Corporation Board on or after May 1, 1996; and (b) has a minimum of five years of service on either the Entergy Corporation Board or a Subsidiary Board, except that service on a Subsidiary Board includes only such service as preceded a non-employee outside director's appointment to the Entergy Corporation Board and is included only if such outside director becomes an outside director on the Entergy Corporation Board.
14. "Potential Change in Control" shall be deemed to have occurred if the event set forth in any one of the following paragraphs shall have occurred:

1. Entergy Corporation or any affiliate or subsidiary company enters into an agreement, the consummation of which would result in the occurrence of a Change in Control; or
2. the Board of Directors adopts a resolution to the effect that, for purposes of this Program, a Potential Change in Control has occurred; or
3. Entergy Corporation or any affiliate or subsidiary company or any person or entity publicly announces an intention to take or to consider taking actions which, if consummated, would constitute a Change in Control; or
4. any person or entity becomes the beneficial owner (as that term is defined in Rule 13d-3 under the Securities Exchange Act of 1934, as amended from time to time), either directly or indirectly, of securities of Entergy Corporation representing twenty percent (20%) or more of either the then outstanding shares of common sto ck of Entergy Corporation or the combined voting power of Entergy Corporation's then outstanding securities (not including in the calculation of the securities beneficially owned by such person or entity any securities acquired directly from Entergy Corporation or its affiliates).

15. "Separation" shall mean the occurrence of any of the following events: (a) the Outside Director's voluntary resignation from, or failure to be re-elected to, the Entergy Corporation Board; (b) the inability of the Outside Director to seek re-election by reason of having attained age 72 as described in Section 5.03; (c) the Outside Director's Disability; (d) the Outside Director's involuntary removal from the Entergy Corporation Board, including the Outside Director's voluntary or involuntary termination from the Entergy Corporation Board under Section 3.08, or (e) the Outside Director's death. An eligible Outside Director shall be considered "Separated" from the Entergy Corporation Board on his or her last day of service as an Outside Director on the Entergy Corporation Board for any of the reasons set forth in this Section 1.15. Notwithstanding the foregoing, a Separation shall not be deemed to occur under the Program unless the event (other than death) also qualifies as a "s eparation from service" within the meaning of section 409A of the Code.
16. "Subsidiary Board" shall mean the board of directors of any corporation 80% or more of whose stock (based on voting power) or value is owned, directly or indirectly, by Entergy Corporation and any partnership or trade or business which is 80% or more controlled, directly or indirectly, by Entergy Corporation.

ARTICLE II

PARTICIPATION

1. Eligible Participants. Except as otherwise provided in Section 3.08, only Outside Directors are eligible for benefits under the Program. For purposes of determining whether a non-employee outside director meets the eligibility criteria of the Program as set forth in Section 1.13, service on a Subsidiary Board shall include service on the Board of Directors of Entergy Gulf States, Inc., or its predecessor.
2. Former Directors Not Eligible. All former eligible directors who separated from the Entergy Corporation Board or any Subsidiary Board prior to May 1, 1996 shall continue to be governed by the terms of the program for outside directors as in effect immediately prior to May 1, 1996. Any former eligible director who separated from the Entergy Corporation Board or any Subsidiary Board prior to May 1, 1996, or who is covered under the prior program for outside directors shall not be eligible to receive any benefits described under this Program. Except as otherwise provided in Section 3.08 in the event of a Change in Control, this Program provides Separation benefits only for Outside Directors who serve on, and subsequently Separate from, the Entergy Corporation Board. Outside Directors will receive benefits for service (on the Entergy Corporation Board and, prior thereto, on a Subsidiary Board) only under this Program.

3. Effective Date. The original effective date of this Program was May 1, 1996; provided, however, that in determining the grant of Equity Units and dividend equivalent rights to eligible Outside Directors pursuant to Sections 3.01 and 3.03, respectively, all years of service that the Outside Director may have on the Entergy Corporation Board (or on a Subsidiary Board prior to joining the Entergy Corporation Board) shall be included in such determination. The effective date of this amendment and restatement of the Program is January 1, 2009.

ARTICLE III

BENEFITS

1. Service Recognition Awards. Subject to Section 5.02, eligible Separated Outside Directors receive 800 Equity Units multiplied times the number of years of service such eligible Separated Outside Director served on the Entergy Corporation Board (or prior thereto on a Subsidiary Board, including the Board of Directors of Entergy Gulf States, Inc., or its predecessor) through the date of his Separation from the Entergy Corporation Board. If the Outside Director serves for a portion of a year, then only a prorated portion of the 800 Equity Units shall be awarded based on the portion of such year he served on the Entergy Corporation Board (or prior thereto on a Subsidiary Board, including the Board of Directors of Entergy Gulf States, Inc., or its predecessor). Except for the survivor's benefits described under Section 3.07, eligible Outside Directors shall not vest in any benefits hereunder unless and until the date on which they are Separated from the Entergy Corporation Board.

2. Concurrent Service. For purposes of calculating years of service under the Program, Entergy Corporation directors will receive credit for any prior years of service as a Subsidiary Board director, unless service on the Subsidiary Board was concurrent with service on the Entergy Corporation Board, in which case credit during such concurrent service period will be given for years of service on the Entergy Corporation Board only.
3. Dividend Equivalent Rights. If Entergy Corporation declares one or more cash dividends respecting Entergy Common Stock to holders of record as of a date or dates occurring on or after the effective date of this Program, an eligible Outside Director shall receive a credit to his account as established under this Program equal in value to the cash dividend paid to a holder of record for each share of Entergy Common Stock multiplied times the number of undistributed Equity Units that such eligible Outside Director has accumulated under the Program based on the formula described in Section 3.01 through such record date based on whole years of service on the Entergy Corporation Board (or prior whole years of service on a Subsidiary Board, including the Board of Directors of Entergy Gulf States, Inc., or its predecessor) through such record date.
4. Payment of Benefits. Commencing on the first day of the month next following an eligible Outside Director's Separation from the Entergy Corporation Board, and thereafter for the four consecutive anniversary dates of such date (the "Annual Installment Dates"), the eligible Separated Outside Director shall be entitled to receive an annual installment payment, as hereinafter determined, based on accumulated Equity Units described in Section 3.01 and dividend equivalent rights described in Section 3.03. Except as provided in the event of death, the five annual installments represent the minimum or earliest payment schedule. An eligible Outside Director shall have no right to demand payment of benefits any sooner than permitted under this schedule. The payment of benefits shall be subject to the following:

1. Each annual installment shall be made within thirty (30) days after the applicable Annual Installment Date. In general, each annual installment represents a proportionate share of the remaining accumulated cash value of Equity Units and dividend equivalent rights accrued by the Outside Director based on the number of remaining annual installments to be paid. For instance, at Separation, the first annual installment shall equal 20% of the total cash value of the accumulated Equity Units and dividend equivalent rights. In the second installment, 25% of the total cash value of the remaining accumulated Equity Units and dividend equivalent rights is payable. In the third installment, 33 1/3% of the total cash value of the remaining accumulated Equity Units and dividend equivalent rights is payable. In the fourth installment, 50% of the total cash value of the remaining accumulated Equity Units and dividend equivalent rights is payable. In the fifth and final installment, the total cash value of the remaining accumulated Equity Units and dividend equivalent rights is distributed.

2. The amount of each such annual installment payment shall be credited against the Outside Director's remaining accumulated Equity Units and dividend equivalent rights in accordance with an irrevocable written election made by the Outside Director no later than December 31, 2008. Such election shall specify that each annual installment will be credited against the Outside Director's accumulated Equity Units and dividend equivalent rights in accordance with one of the following choices: (1) first against all accumulated dividend equivalent rights and then against accumulated Equity Units; (2) first against all accumulated Equity Units and then against accumulated dividend equivalent rights; or (3) pro-rata against remaining accumulated Equity Units and dividend equivalent rights, based on the value of each as of the close of business on the last business day immediately preceding the applicable Annual Installment Date. If no election in this regard is made by the Outside Director prior to his initia l Annual Installment Date, then the amount of each such annual installment shall be credited in accordance with choice (3) above.
3. Each annual installment shall be paid in the form of cash based upon the closing price of Entergy Common Stock on the New York Stock Exchange as of the close of business on the last business day immediately preceding the applicable Annual Installment Date. No participation or payment under this Program shall be in the form of actual shares of Entergy Common Stock. Subject to Section 3.07, all installments payable under this Program shall cease upon the distribution of all five installments. If the Outside Director dies after Separation from the Entergy Corporation Board, but before all five installments have been paid, the Outside Director's remaining unpaid accrued benefits under this Program (based on the closing price of Entergy Common Stock on the New York Stock Exchange as of the close of business on the last business day occurring immediately preceding the Outside Director's death) shall be paid in a lump sum, within thirty (30) days after the date of his death, to his designated beneficia ry on file with the Secretary to the Entergy Corporation Board or, in the absence of any such named beneficiary, to the estate of the Outside Director.
4. Notwithstanding the foregoing, an eligible Outside Director may, at least one year prior to Separation from the Entergy Corporation Board and subject to consent from Entergy Corporation, execute a written deferral election under which the commencement of the five annual installments under this Program may be irrevocably deferred for a fixed number of years, equal to at least five years but not to exceed fifteen (15) years from the date of such Outside Director's Separation from the Entergy Corporation Board. If the Outside Director executes such a deferral election, Separates and subsequently dies prior to the deferred commencement date for the installments, the survivor's benefit provisions described in Section 3.07 shall apply.

5. Other Benefits.

Life Insurance - Eligible Outside Directors of the Entergy Corporation Board who have at least 10 years of service will continue to receive $25,000 of life insurance coverage after Separation at no cost to the Outside Director.

6. Adjustments Upon Changes in Capitalization. The service recognition awards described under Sections 3.01 and 3.03, respectively, shall be subject to adjustment as deemed necessary by the Entergy Corporation Board to avoid dilution or enlargement of the value of the Equity Units or dividend equivalent rights hereunder, including adjustments made necessary to avoid dilution or enlargement of such rights hereunder resulting from changes in the Entergy Common Stock by reason of stock dividends, stock splits, recapitalizations, mergers, consolidations, combinations or exchanges of shares, separations, reorganizations, liquidations and the like. Any such determination by the Entergy Corporation Board shall be binding.
7. Death While In Active Service on the Board. If an Outside Director dies while serving on the Entergy Corporation Board, all benefits payable under the Program shall be paid in a lump sum to the beneficiary named by the Outside Director, or, in the absence of a named beneficiary, to the estate of the Outside Director as soon as administratively practicable following the Participant's death or a later date within the same taxable year as the Participant's death or, if later, by the 15th day of the third month following the Participant's death. A beneficiary designation shall be effective only if in writing, signed by the Outside Director and filed with the Secretary of the Entergy Corporation Board prior to the death of the Outside Director.
8. Change in Control.

1. Notwithstanding anything stated herein to the contrary, if there should occur a Change in Control and if, within the Change in Control Period, an Outside Director (which solely for purposes of this Section 3.08 shall also include any outside director of the Entergy Corporation Board who satisfies all of the requirements of Section 1.13 except the 5-year eligibility requirement) is involuntarily terminated from the Entergy Corporation Board or otherwise loses his status as an outside director on the Entergy Corporation Board for reasons other than for Cause within the Change in Control Period, such Outside Director shall fully vest in, and have a nonforfeitable right to, all benefits accrued under the Program (or that would have accrued under the Program if the outside director were not subject to the 5-year eligibility requirement of Section 1.13) as of the date of any such termination, and no amendment or termination of the Program shall reduce such vested accrued benefit. In any such eve nt, the Outside Director may commence his or her benefits hereunder without the consent of Entergy Corporation or its successor as of the first day of the month next following his or her termination or Separation from the Entergy Corporation Board. Any termination of the Outside Director from the Entergy Corporation Board within the Change in Control Period, whether voluntarily or involuntarily, may, at the Outside Director's sole discretion, be deemed a Separation hereunder.
2. Notwithstanding any provision of this Program to the contrary, any amendment to, or termination of, the Program following a Change of Control shall not reduce the level of benefits accrued under this Program (or the level of benefits that would have accrued under the Program if the outside director were not subject to the 5-year eligibility requirement of Section 1.13) through the date of any such amendment or termination. In no event shall an Outside Director's benefit accrued under this Program following a Change of Control be less than the benefit accrued by such Outside Director under this Program (or the benefit that would have accrued under the Program if the outside director were not subject to the 5-year eligibility requirement of Section 1.13) immediately prior to the Change of Control Period.
3. Nothing stated herein shall prohibit Entergy Corporation from adopting or establishing a trust or other means for funding any obligations created hereunder provided, however, any and all rights that any such Outside Directors shall have with respect to any such trust or other fund shall be governed by the terms thereof. Notwithstanding the foregoing, no contributions shall be made to such a trust during any "restricted period" within the meaning of section 409A(b)(3) of the Code.
4. Unless prohibited by Section 3.08(c) hereof, within thirty (30) days following the date of a Change of Control, Entergy Corporation shall make a single irrevocable lump sum contribut ion to the Trust for Deferred Payments of Entergy Corporation and Subsidiaries ("Trust") pursuant to the terms and conditions described in such Trust. Such contribution shall be in an amount equal to the total benefits accrued by the eligible Outside Directors and their beneficiaries under the Program (or the benefits that would have accrued under the Program if the outside director were not subject to the 5-year eligibility requirement of Section 1.13) through the date of any such Change of Control. If an Outside Director shall continue to serve as an Outside Director on the Entergy Corporation Board after a Change of Control, an additional amount shall be contributed by Entergy Corporation to the Trust each calendar year, if necessary, in order to maintain a lump sum amount credited to Entergy Corporation's Program account under the Trust that is equal to the total unpaid benefits accrued by the Outside Directors (including the total unpaid benefits that would have accrued under the Progra m if the outside director were not subject to the 5-year eligibility requirement of Section 1.13) as of the end of each applicable calendar year. Notwithstanding the foregoing sentence and this subsection to the contrary, Entergy Corporation may make contributions to the Trust prior to a Change of Control in such amounts as it shall determine in its complete discretion. The Trust is intended as a "grantor" trust under the Internal Revenue Code and the establishment and funding of such Trust is not intended to cause Outside Directors to realize current income on amounts contributed thereto, and the Trust shall be so interpreted.

9. Required Six-Month Delay for Certain Distributions. Notwithstanding the foregoing, no

distributions may be paid to an Outside Director within six months following the Outside Director's Separation, if the Outside Director is a "specified employee" within the meaning of Code section 409A at the time of Separation. For this purpose, specified employee generally means a Key Employee of Entergy Corporation at a time when Entergy Corporation or any member of a controlled group of corporations that includes Entergy Corporation is publicly traded on an established securities market whether inside or outside the United States. Whether an individual is a specified employee shall be determined by the Administrator under rules established in regulations under Code section 409A and such determination shall be final and binding. Any payments that are delayed pursuant to this Section 3.09 shall be paid in full immediately after the six-month required delay period ends.

ARTICLE IV

PROGRAM ADMINISTRATION

1. Administration of the Program. The Senior Vice-President, Human Resources and Administration for Entergy Services, Inc. is the Administrator of this Program and is responsible for its interpretation and maintenance. The Administrator shall operate and administer the Program and, as such, shall have the authority as Administrator to exercise the powers and discretion conferred on it by the Program, including the right to delegate any function to a specified person or persons.
2. Board Approval. The Entergy Corporation Board must approve any deviations from this Program relating to the amount of compensation or benefits of Outside Directors.
3. Powers of the Administrator. The Administrator and any of its delegees shall administer the Program in accordance with its terms and shall have all powers, authority, and discretion necessary or proper for such purpose. In furtherance of this duty, the Administrator shall have the sole and exclusive power and discretion to make factual determinations, construe and interpret the Program, including the intent of the Program and any ambiguous, disputed or doubtful provisions of the Program. All findings, decisions, or determinations of any type made by the Administrator, including factual determinations and any interpretation or construction of the Program, shall be final and binding on all parties and shall not be disturbed unless the Administrator's decisions are arbitrary and capricious. The Administrator shall be the sole judge of the standard of proof required in any claim for benefits and/or in any question of eligibility for a benefit. By way of example, the Administrator shall have the sole an d exclusive power and discretion:

1. to adopt such rules and regulations as it shall deem desirable or necessary for the administration of the Program on a consistent and uniform basis;
2. to interpret the Program including, without limitation, the power to use Administrator's sole and exclusive discretion to construe and interpret (1) the Program, (2) the intent of the Program, and (3) any ambiguous, disputed or doubtful provisions of the Program;
3. to determine all questions arising in the administration of the Program including, but not limited to, the power and discretion to determine rights or eligibility of any claimant to receive benefits under the Program;
4. to require such information as the Administrator may reasonably request from any Participant or claimant as a condition for receiving any benefit under the Program;
5. to grant and/or deny any and all claims for benefits, and construe any and all issues of Program interpretation and/or fact issues relating to eligibility for benefits;
6. to compute the amount and determine the manner and timing of any benefits payable under the Program;
7. to execute or deliver any instrument or make any payment on behalf of the Program;
8. to employ one or more persons to render advice with respect to any of the Administrator's responsibilities under the Program;
9. to direct all payments that shall be made pursuant to the terms of the Program; and
10. to make findings of fact, to resolve disputed fact issues, and to make determinations based on the facts and evidence contained in the administrative record developed during the claims review procedure.

For any acts not specifically enumerated above, when applying, construing, or interpreting any and all Program provisions and/or fact questions presented in claims for benefits, the Administrator shall have the same discretionary powers as enumerated above.

The Plan is intended to satisfy the requirements of section 409A of the Code and the Administrator shall interpret the Plan and exercise the power and discretion conferred under the Plan in a manner that is at all times consistent with the requirements of Code section 409A.

4. Reliance on Reports and Certificates. The Administrator may rely conclusively upon all tables, valuations, certificates, opinions and reports furnished by an actuary, accountant, counsel or other person who may from time to time be employed or engaged for such purposes.
5. Claims Administration. The Administrator may appoint and, in its sole discretion, remove a Claims Administrator and/or Claims Appeal Administrator to administer claims for benefits under the Program in accordance with its terms, and such delegees shall have all powers, authority, and discretion necessary or proper for such purpose. In the absence of such appointment, the Administrator shall be the Claims Administrator and Claims Appeal Administrator.
6. Filing Benefit Claims. Any claim asserting entitlement to a benefit under the Program must be asserted within 90 days after the event giving rise to the claim by sending written notice of the claim to the Claims Administrator. The written notice of the claim must be accompanied by any and all documents, materials, or other evidence allegedly supporting the claim for benefits. If the claim is granted, the claimant will be so notified in writing by the Claims Administrator.
7. Denial or Partial Denial of Benefit Claims. If the Claims Administrator denies a claim for benefits in whole or part, the Claims Administrator shall notify the claimant in writing of the decision within 90 days after the claim has been received by the Claims Administrator. In the Claim Administrator's sole discretion, the Claims Administrator may extend the time to decide the claim for an additional 90 days, by giving written notice of the need for such an extension any time prior to the expiration of the initial 90 day period. The Claims Administrator, in its sole discretion, reserves the right to request specific information from the claimant, and reserves the right to have the claimant examined or tested by person(s) employed or compensated by the Program. If the claim is denied or partially denied, the Claims Administrator shall provide the claimant with written notice stating:

1. the specific reasons for the denial of the claim (including the facts upon which the denial was based) and reference to any pertinent Program provisions on which the denial is based;

2. (b) if applicable, a description of any additional material or information necessary for claimant to perfect the claim and an explanation of why such material or information is necessary; and

3. (c) an explanation of the claims review appeal procedure including the name and address of the person or committee to whom any appeal should be directed.

8. Appeal of Claims That Are Denied or Partially Denied. The claimant may request review of the Claims Administrator's denial or partial denial of a claim for Program benefits. Such request must be made in writing within 60 days after claimant has received notice of the Claims Administrator's decision and shall include with the written request for an appeal any and all documents, materials, or other evidence which claimant believes supports his or her claim for benefits. The written request for an appeal, together with all documents, materials, or other evidence which claimant believes supports his or her claim for benefits should be addressed to the Claims Administrator, who will be responsible for submitting the appeal for review to the Claims Appeal Administrator.
9. The Appeal Process. The Claims Administrator will submit the appeal to the Claims Appeal Administrator for review of the denial or partial denial of the claim. Within 60 days after the receipt of claimant's appeal, the claimant will be notified of the final decision of the Claims Appeal Administrator, unless, in the Claims Appeal Administrator's sole discretion, circumstances require an extension of this period for up to an additional 60 days. If such an extension is required, the Claims Appeal Administrator shall notify claimant of this extension in writing before the expiration of the initial 60-day period. During the appeal, the Claims Appeal Administrator, in its sole discretion, reserves the right to request specific information from the claimant, and reserves the right to have the claimant examined or tested by person(s) employed or compensated by the Program. The final decision of the Claims Appeal Administrator shall set forth in writing the facts and Progra m provisions upon which the decision is based. All decisions of the Claims Appeal Administrator are final and binding on Outside Directors, their beneficiaries, or other claimants.
10. Judicial Proceedings for Benefits. No claimant may file suit in court to obtain benefits under the Program without first completely exhausting all stages of this claims review process. In any event, no legal action seeking Program benefits may be commenced or maintained against the Program more than ninety (90) days after the Claims Appeal Administrator's decision on appeal.

ARTICLE V

PROCEDURES

1. Written Notification. Upon Separation of an Entergy Corporation Board member, the Secretary of the Entergy Corporation Board will provide written notification of the director's official retirement date and any other pertinent information to the Administrator.
2. Amendment or Termination. Except as otherwise provided herein, and subject to the requirements of Code section 409A, this Program shall be subject to amendment or termination by a majority vote of the Entergy Corporation Board at any time. Any such amendment or termination shall be binding on all eligible Separated directors and active directors alike regardless of their status, provided, however, that no such amendment or termination shall affect an eligible Separated Outside Director's rights to any and all recognition awards or benefits accrued prior to the effective date of any such amendment or termination. Notwithstanding the foregoing, unless specifically provided, no amendment shall "materially modify" benefits under the Program, within the meaning of section 409A of the Code, that become earned and vested on or before December 31, 2004.
3. Maximum Age. Outside directors cannot stand for re-election to the Entergy Corporation Board after their 72^nd birthday.
4. Program Summary. A summary of the Entergy Corporation Service Recognition Program shall be attached to this Program as Attachment 1.

5. Section 409A. The Program is intended to comply with the applicable requirements of Section 409A of the Code and the regulations thereunder, and shall be administered in accordance with Section 409A and the regulations thereunder to the extent Section 409A and the regulations thereunder apply to the Program. To the extent that any provision of the Program would cause a conflict with the requirements of Section 409A and the regulations thereunder, or would cause the administration of the Program to fail to satisfy such requirements, such provision shall be deemed null and void to the extent permitted by applicable law.

ATTACHMENT 1 TO ENTERGY CORPORATION SERVICE RECOGNITION PROGRAM FOR NON-EMPLOYEE OUTSIDE DIRECTORS
ELIGIBILITY	5 YEARS SERVED ON ENTERGY CORPORATION BOARD  (but including service on a Subsidiary Board prior to serving as an  Outside Director on the Entergy Corporation Board)
ANNUAL BENEFIT	800 EQUITY UNITS PER YEAR OF SERVICE ON THE  ENTERGY CORPORATION BOARD (INCLUDING PRIOR  YEARS OF SERVICE ON A SUBSIDIARY BOARD) PAID  OVER NO LESS THAN 5 YEARS. CUMULATIVE EQUITY  UNITS SHALL NOT EXCEED 8,000 EQUITY UNITS.
MAXIMUM AGE	AGE 72
AT DEATH	SURVIVOR'S BENEFITS IF ELIGIBLE DIRECTOR DIES  WHILE IN ACTIVE SERVICE ON THE ENTERGY  CORPORATION BOARD; SURVIVOR'S BENEFITS ALSO  AVAILABLE IF ELIGIBLE DIRECTOR DIES AFTER  SEPARATION, BUT BEFORE FINAL DISTRIBUTION
TREATMENT OF  PREVIOUSLY  SEPARATED  DIRECTORS	BENEFIT IN EFFECT PRIOR TO EFFECTIVE DATE WILL  CONTINUE TO BE PROVIDED

This Attachment 1 is provided merely as a summary of the benefits under the Program and does not represent a binding description of such benefits. For a full description of the benefits available under the Program, please refer to the Program document. If there is any conflict between this summary and the Program document, the Program document shall control.

EX-10

Entergy Corporation Outside Director Stock Program Established under the 2007 Equity Ownership and Long Term Cash Incentive Plan of Entergy Corporation and Subsidiaries
(Amended and Restated Effective January 1, 2009)

1. General

The Entergy Corporation Outside Director Stock Program ("Program") was established pursuant to Article X of the 2007 Equity Ownership and Long Term Cash Incentive Plan of Entergy Corporation and Subsidiaries (Effective for Grants and Elections On or After January 1, 2007) (the "Plan"), the terms of which are incorporated into the Program. References in this Program to any specific Plan provision do not limit the applicability of any other Plan provision. The effective date of the Program is January 1, 2007. Capitalized terms used in the Program have the meanings assigned to those terms in the Plan.

The Program is hereby further amended and restated effective January 1, 2009 to implement changes required pursuant to and consistent with section 409A of the internal Revenue Code ("Code") for amounts deferred on or after January 1, 2005. Between January 1, 2007 and December 31, 2008, the Program has been operated in accordance with transition relief established by the Treasury Department and Internal Revenue Service under Code section 409A. This amendment and restatement is adopted in conformity with final regulations under Code section 409A issued by the Treasury Department on April 10, 2007 and effective January 1, 2009.

2. Purpose

The purpose of the Program is to promote the interests of Entergy Corporation (the "Company") and its shareholders by attracting and retaining Outside Directors of outstanding ability and enabling Outside Directors to participate in the long-term growth and financial success of the Company.

3. Eligibility

The only persons eligible to participate in the Program are Outside Directors.

4. Administration

Pursuant to Article IV of the Plan, the Board of Directors of the Company shall administer the Plan with respect to any Award granted to an Outside Director; provided, however, that the Board of Directors may delegate its authority to administer the Program to any committee or subcommittee of the Board of Directors which is comprised solely of Outside Directors.

5. Quarterly Stock Awards

5.1. Quarterly Stock Awards. Subject to the provisions of Section 12 of the Plan and Sections 6 and 7 of the Program, each Outside Director shall receive 150 shares of Common Stock ("Quarterly Stock Award") on an Award Date (as defined in Section 5.3 below) for serving as an Outside Director during the entire calendar quarter ending on, or immediately prior to, such Award Date.

5.2. Consideration. Each Quarterly Stock Award is granted in exchange for services rendered during the calendar quarter ending on, or immediately prior to, the Award Date and does not require the payment of consideration.

5.3. Award Dates. The Quarterly Stock Awards will be granted as of the following dates or, if the date is a day on which the New York Stock Exchange ("NYSE") is not open for trading, the next succeeding NYSE trading day (each an "Award Date"):

• May 31
• August 31
• November 30
• February 28

5.4. Proration. If an Outside Director serves as an Outside Director for less than the full calendar quarter, the number of shares of Common Stock awarded to the Outside Director shall be calculated by multiplying (a) 150 by (b) the fraction that results from dividing the number of days the individual served as an Outside Director during the applicable calendar quarter by 90 days.

5.5. Employment by System Company. If an Outside Director subsequently becomes an employee of a System Company while remaining a member of the Board, the former Outside Director's participation in the Program will be terminated effective immediately upon his or her employment by the System Company. The change in the Outside Director's employment status shall have no effect on Quarterly Stock Awards granted prior to his or her employment by a System Company; provided that the former Outside Director shall be entitled to a pro rata Award for such calendar quarter in accordance with Section 5.4.

5.6. Taxes. If required by applicable law, the Outside Director shall pay to the Company any amount necessary to satisfy applicable federal, state or local tax withholding requirements attributable to the Quarterly Stock Awards promptly upon notification of the amounts due. If required to pay withholding taxes, the Outside Director may elect to pay such taxes from the shares of Common Stock that otherwise would be distributed to such Outside Director, or from a combination of cash and shares of Common Stock. As provided in Section 12.3 of the Plan, Common Stock related to that portion of an Award utilized for the payment of withholding taxes shall not again be available for Awards under the Plan.

5.7. Delivery. The Company may deliver shares of Common Stock representing a Quarterly Stock Award by book-entry credit to the account of the Outside Director or by the delivery of certificated shares. The Company may affix to these shares any legend that the Company determines to be necessary or advisable.

6.0  Deferral

In lieu of taking delivery of shares of Common Stock on an Award Date, an Outside Director may elect to defer the receipt of such Quarterly Stock Award to a subsequent calendar year provided that he or she files an irrevocable written deferral notice with the Board of Directors no later than the 31^st day of December of the calendar year immediately preceding the calendar year in which the services are rendered to which the Award Date relates. Accordingly, such a deferral notice must be filed by December 31 for the Award Dates immediately following on the next May 31, August 31, and November 30 of the immediately following year and on February 28 of the second calendar year immediately following the year in which the deferral notice is filed. The Outside Director's written deferral election must specify the date on which the shares of Common Stock will be issued ("Payment Date"), which Payment Date must be no earlier than January 2nd of the third calendar year im mediately following the end of the calendar year in which the deferral election is made. Shares of Common Stock deferred pursuant to this section shall accrue dividend equivalents, which dividend equivalents will be paid on the Payment Date together with interest calculated at an annual rate based upon the 52 week Treasury Bill rate as in effect on the first business day of each year. All deferral rights or provisions contained in this Program shall be subject to all conditions, restraints and limitations as may from time to time be imposed by the 2007 Plan, including, without limitation, any amendments to such 2007 Plan made pursuant to section 409A of the Internal Revenue Code and any and all regulations and guidance released thereunder. Such limitation will restrict the ability of an Outside Director to accelerate the distribution of any deferred Quarterly Stock Awards together with other restrictions.

7.0  Miscellaneous

The Board of Directors reserves the right at any time to amend the terms and conditions set forth in this Program to the extent permitted under the Plan. Further, the Program is intended to comply with the applicable requirements of Code section 409A and the regulations thereunder and shall be administered in accordance with section 409A and the regulations thereunder to the extent the program is subject thereto. To the extent that any provision of the Program would conflict with the requirements of section 409A and the regulations thereunder or would cause the administration of the Program to fail to satisfy such requirements, such provision shall be deemed null and void to the extent permitted by applicable law.

EX-12

					Exhibit 12(a)
Entergy Arkansas, Inc.
Computation of Ratios of Earnings to Fixed Charges and
Ratios of Earnings to Combined Fixed Charges and Preferred Dividends
	Twelve Months Ended
	December 31,					June 30,
	2003	2004	2005	2006	2007	2008
Total Interest Charges	$91,221	$84,430	$84,992	$85,809	$91,740	$86,475
Interest applicable to rentals	15,425	13,171	13,911	11,145	10,919	11,576
Total fixed charges, as defined	106,646	97,601	98,903	96,954	102,659	98,051
Preferred dividends, as defined (a)	14,274	12,646	12,093	10,041	11,104	11,531
Combined fixed charges and preferred dividends, as defined	$120,920	$110,247	$110,996	$106,995	$113,763	$109,582
Earnings as defined:
Net Income	$126,009	$142,210	$174,635	$173,154	$139,111	$129,875
Add:
Provision for income taxes:
Total	105,296	89,064	96,949	56,824	85,638	85,391
Fixed charges as above	106,646	97,601	98,903	96,954	102,659	98,051
Total earnings, as defined	$337,951	$328,875	$370,487	$326,932	$327,408	$313,317
Ratio of earnings to fixed charges, as defined	3.17	3.37	3.75	3.37	3.19	3.20
Ratio of earnings to combined fixed charges and
preferred dividends, as defined	2.79	2.98	3.34	3.06	2.88	2.86
- ------------------------
(a) "Preferred dividends," as defined by SEC regulation S-K, are computed by dividing the preferred dividend requirement by one hundred percent (100%) minus the income tax rate.

EX-12

					Exhibit 12(b)
Entergy Gulf States Louisiana, L.L.C.
Computation of Ratios of Earnings to Fixed Charges and
Ratios of Earnings to Combined Fixed Charges and Preferred Dividends
	Twelve Months Ended
	December 31,					June 30,
	2003	2004	2005	2006	2007	2008
Fixed charges, as defined:
Total Interest charges	$157,343	$133,598	$126,788	$149,780	$163,409	$150,069
Interest applicable to rentals	16,694	13,707	8,832	8,928	8,773	6,589
Total fixed charges, as defined	174,037	147,305	135,620	158,708	172,182	156,658
Preferred dividends, as defined (a)	6,485	6,991	6,444	5,969	6,514	3,994
Combined fixed charges and preferred dividends, as defined	$180,522	$154,296	$142,064	$164,677	$178,696	$160,652
Earnings as defined:
Income from continuing operations before extraordinary items and
the cumulative effect of accounting changes	$63,895	$192,264	$206,497	$211,988	$192,779	$187,235
Add:
Income Taxes	24,249	108,288	110,270	107,067	123,701	118,458
Fixed charges as above	174,037	147,305	135,620	158,708	172,182	156,658
Total earnings, as defined	$262,181	$447,857	$452,387	$477,763	$488,662	$462,351
Ratio of earnings to fixed charges, as defined	1.51	3.04	3.34	3.01	2.84	2.95
Ratio of earnings to combined fixed charges and
preferred dividends, as defined	1.45	2.90	3.18	2.90	2.73	2.88
(a) "Preferred dividends," as defined by SEC regulation S-K, are computed by dividing the preferred dividend requirement by one hundred percent (100%) minus the income tax rate.

EX-12

					Exhibit 12(c)
Entergy Louisiana, LLC
Computation of Ratios of Earnings to Fixed Charges and
Ratios of Earnings to Combined Fixed Charges and Preferred Distributions
	Twelve Months Ended
	December 31,					June 30,
	2003	2004	2005	2006	2007	2008
Fixed charges, as defined:
Total Interest	$76,756	$74,141	$85,418	$92,216	$85,729	$81,945
Interest applicable to rentals	6,359	5,595	4,585	4,833	7,074	5,708
Total fixed charges, as defined	$83,115	$79,736	$90,003	$97,049	$92,803	87,653
Preferred distributions, as defined (a)	-	-	-	10,906	10,998	11,252
Combined fixed charges and preferred distributions, as defined	$83,115	$79,736	$90,003	$107,955	$103,801	$98,905
Earnings as defined:
Net Income	$146,154	$127,495	$128,082	$137,618	$143,337	$144,910
Add:
Provision for income taxes:
Total Taxes	97,408	79,475	96,819	78,338	83,494	89,821
Fixed charges as above	83,115	79,736	90,003	97,049	92,803	87,653
Total earnings, as defined	$326,677	$286,706	$314,904	$313,005	$319,634	$322,384
Ratio of earnings to fixed charges, as defined	3.93	3.60	3.50	3.23	3.44	3.68
Ratio of earnings to combined fixed charges and
preferred distributions, as defined	- -	- -	- -	2.90	3.08	3.26
(a) "Preferred distributions," as defined by SEC regulation S-K, are computed by dividing the preferred distribution requirement by one hundred percent (100%) minus the income tax rate.

EX-12

					Exhibit 12(d)
Entergy Mississippi, Inc.
Computation of Ratios of Earnings to Fixed Charges and
Ratios of Earnings to Combined Fixed Charges and Preferred Dividends
	Twelve Months Ended
	December 31,					June 30,
	2003	2004	2005	2006	2007	2008
Fixed charges, as defined:
Total Interest	$47,464	$44,637	$43,707	$51,216	$47,020	$46,909
Interest applicable to rentals	1,880	1,162	771	1,427	1,577	1,350
Total fixed charges, as defined	$49,344	$45,799	$44,478	$52,643	$48,597	48,259
Preferred dividends, as defined (a)	5,099	5,067	5,129	4,373	4,144	4,315
Combined fixed charges and preferred dividends, as defined	$54,443	$50,866	$49,607	$57,016	$52,741	$52,574
Earnings as defined:
Net Income	$67,058	$73,497	$62,103	$52,285	$72,106	$73,175
Add:
Provision for income taxes:
Total income taxes	34,431	37,040	33,952	28,567	35,850	39,446
Fixed charges as above	49,344	45,799	44,478	52,643	48,597	48,259
Total earnings, as defined	$150,833	$156,336	$140,533	$133,495	$156,553	$160,880
Ratio of earnings to fixed charges, as defined	3.06	3.41	3.16	2.54	3.22	3.33
Ratio of earnings to combined fixed charges and
preferred dividends, as defined	2.77	3.07	2.83	2.34	2.97	3.06
- ------------------------
(a) "Preferred dividends," as defined by SEC regulation S-K, are computed by dividing the preferred dividend requirement by one hundred percent (100%) minus the income tax rate.

EX-12

					Exhibit 12(e)
Entergy New Orleans, Inc.
Computation of Ratios of Earnings to Fixed Charges and
Ratios of Earnings to Combined Fixed Charges and Preferred Dividends
	Twelve Months Ended
	December 31,					June 30,
	2003	2004	2005	2006	2007	2008
Fixed charges, as defined:
Total Interest	$17,786	$16,610	$13,555	$19,329	$21,497	$19,160
Interest applicable to rentals	910	644	426	527	407	438
Total fixed charges, as defined	18,696	17,254	13,981	19,856	21,904	19,598
Preferred dividends, as defined (a)	1,686	1,545	1,172	2,501	1,745	1,787
Combined fixed charges and preferred dividends, as defined	$20,382	$18,799	$15,153	$22,357	$23,649	$21,385
Earnings as defined:
Net Income	$7,859	$28,072	$1,250	$5,344	$24,582	28,992
Add:
Provision for income taxes:
Total	5,875	16,868	1,790	5,051	13,506	17,132
Fixed charges as above	18,696	17,254	13,981	19,856	21,904	19,598
Total earnings, as defined	$32,430	$62,194	$17,021	$30,251	$59,992	$65,722
Ratio of earnings to fixed charges, as defined	1.73	3.60	1.22	1.52	2.74	3.35
Ratio of earnings to combined fixed charges and
preferred dividends, as defined	1.59	3.31	1.12	1.35	2.54	3.07
- ------------------------
(a) "Preferred dividends," as defined by SEC regulation S-K, are computed by dividing the preferred dividend requirement by one hundred percent (100%) minus the income tax rate.

EX-12

					Exhibit 12(f)
Entergy Texas, Inc.
Computation of Ratios of Earnings to Fixed Charges
	Twelve Months Ended
	December 31,					June 30,
	2003	2004	2005	2006	2007	2008
Fixed charges, as defined:
Total Interest	$76,812	$65,220	$59,882	$70,479	$85,250	$86,972
Interest applicable to rentals	5,183	4,255	2,299	2,356	3,572	1,781
Total fixed charges, as defined	81,995	69,475	62,181	72,835	88,822	$88,753
Earnings as defined:
Net Income	$12,038	$51,136	$48,916	$54,137	$58,921	$91,607
Add:
Provision for income taxes:
Total	5,489	23,318	17,192	27,325	36,249	50,567
Fixed charges as above	81,995	69,475	62,181	72,835	88,822	88,753
Total earnings, as defined	$99,522	$143,929	$128,289	$154,297	$183,992	$230,927
Ratio of earnings to fixed charges, as defined	1.21	2.07	2.06	2.12	2.07	2.60

EX-12

						Exhibit 12(g)
System Energy Resources, Inc.
Computation of Ratios of Earnings to Fixed Charges
	Twelve Months Ended
	December 31,					June 30,
	2003	2004	2005	2006	2007	2008
Fixed charges, as defined:
Total Interest	$64,620	$58,928	$60,424	$59,931	$57,117	$56,739
Interest applicable to rentals	3,793	3,426	3,039	3,914	4,463	4,711
Total fixed charges, as defined	$68,413	$62,354	$63,463	$63,845	$61,580	$61,450
Earnings as defined:
Net Income	$106,003	$105,948	$111,644	$140,258	$136,081	$125,512
Add:
Provision for income taxes:
Total	75,845	78,013	69,343	54,529	45,447	38,050
Fixed charges as above	68,413	62,354	63,463	63,845	61,580	61,450
Total earnings, as defined	$250,261	$246,315	$244,450	$258,632	$243,108	$225,012
Ratio of earnings to fixed charges, as defined	3.66	3.95	3.85	4.05	3.95	3.66

EX-31

Exhibit 31(a)

CERTIFICATIONS

	I, J. Wayne Leonard, certify that:
1.	I have reviewed this quarterly report on Form 10-Q of Entergy Corporation;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.	The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
	a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
	b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

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

Date: August 7, 2008

EX-31

Exhibit 31(b)

CERTIFICATIONS

	I, Leo P. Denault, certify that:
1.	I have reviewed this quarterly report on Form 10-Q of Entergy Corporation;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.	The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
	a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
	b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

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

Date: August 7, 2008

EX-31

Exhibit 31(c)

CERTIFICATIONS

	I, Hugh T. McDonald, certify that:
1.	I have reviewed this quarterly report on Form 10-Q of Entergy Arkansas, Inc.;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.	The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
	a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
	b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Hugh T. McDonald
Hugh T. McDonald
Chairman, President, and Chief Executive Officer of
Entergy Arkansas, Inc.

Date: August 7, 2008

EX-31

Exhibit 31(d)

CERTIFICATIONS

	I, Jay A. Lewis, certify that:
1.	I have reviewed this quarterly report on Form 10-Q of Entergy Arkansas, Inc.;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.	The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
	a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
	b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Arkansas, Inc.

Date: August 7, 2008

EX-31

Exhibit 31(e)

CERTIFICATIONS

	I, E. Renae Conley, certify that:
1.	I have reviewed this quarterly report on Form 10-Q of Entergy Gulf States Louisiana, L.L.C.;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.	The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
	a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
	b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ E. Renae Conley
E. Renae Conley
Chair of the Board, President and Chief Executive
Officer of Entergy Gulf States Louisiana, L.L.C.

Date: August 7, 2008

EX-31

Exhibit 31(f)

CERTIFICATIONS

	I, Jay A. Lewis, certify that:
1.	I have reviewed this quarterly report on Form 10-Q of Entergy Gulf States Louisiana, L.L.C.;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.	The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
	a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
	b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Gulf States Louisiana, L.L.C.

Date: August 7, 2008

EX-31

Exhibit 31(g)

CERTIFICATIONS

	I, E. Renae Conley, certify that:
1.	I have reviewed this quarterly report on Form 10-Q of Entergy Louisiana, LLC;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.	The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
	a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
	b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ E. Renae Conley
E. Renae Conley
Chair of the Board, President, and Chief Executive Officer of
Entergy Louisiana, LLC

Date: August 7, 2008

EX-31

Exhibit 31(h)

CERTIFICATIONS

	I, Jay A. Lewis, certify that:
1.	I have reviewed this quarterly report on Form 10-Q of Entergy Louisiana, LLC;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.	The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
	a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
	b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Louisiana, LLC

Date: August 7, 2008

EX-31

Exhibit 31(i)

CERTIFICATIONS

	I, Haley R. Fisackerly, certify that:
1.	I have reviewed this quarterly report on Form 10-Q of Entergy Mississippi, Inc.;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.	The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
	a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
	b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Haley R. Fisackerly
Haley R. Fisackerly
Chairman of the Board, President, and Chief Executive Officer
of Entergy Mississippi, Inc.

Date: August 7, 2008

EX-31

Exhibit 31(j)

CERTIFICATIONS

	I, Jay A. Lewis, certify that:
1.	I have reviewed this quarterly report on Form 10-Q of Entergy Mississippi, Inc.;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.	The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
	a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
	b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Mississippi, Inc.

Date: August 7, 2008

EX-31

Exhibit 31(k)

CERTIFICATIONS

	I, Roderick K. West, certify that:
1.	I have reviewed this quarterly report on Form 10-Q of Entergy New Orleans, Inc.;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.	The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
	a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
	b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Roderick K. West
Roderick K. West
Chairman, President and Chief Executive Officer of
Entergy New Orleans, Inc.

Date: August 7, 2008

EX-31

Exhibit 31(l)

CERTIFICATIONS

	I, Jay A. Lewis, certify that:
1.	I have reviewed this quarterly report on Form 10-Q of Entergy New Orleans, Inc.;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.	The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
	a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
	b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy New Orleans, Inc.

Date: August 7, 2008

EX-31

Exhibit 31(m)

CERTIFICATIONS

	I, Joseph F. Domino, certify that:
1.	I have reviewed this quarterly report on Form 10-Q of Entergy Texas, Inc.;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.	The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
	a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
	b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Joseph F. Domino
Joseph F. Domino
Chairman, President, and Chief Executive Officer of
Entergy Texas, Inc.

Date: August 7, 2008

EX-31

Exhibit 31(n)

CERTIFICATIONS

	I, Jay A. Lewis, certify that:
1.	I have reviewed this quarterly report on Form 10-Q of Entergy Texas, Inc.;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.	The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
	a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
	b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Texas, Inc.

Date: August 7, 2008

EX-31

Exhibit 31(o)

CERTIFICATIONS

	I, Michael R. Kansler, certify that:
1.	I have reviewed this quarterly report on Form 10-Q of System Energy Resources, Inc.;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.	The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
	a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
	b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Michael R. Kansler
Michael R. Kansler
Chairman, President, and Chief Executive Officer of
System Energy Resources, Inc.

Date: August 7, 2008

EX-31

Exhibit 31(p)

CERTIFICATIONS

	I, Wanda C. Curry, certify that:
1.	I have reviewed this quarterly report on Form 10-Q of System Energy Resources, Inc.;
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4.	The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
	a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
	b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
	c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
	d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and
5.	The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):
	a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and
	b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Wanda C. Curry
Wanda C. Curry
Vice President and Chief Financial Officer
of System Energy Resources, Inc.

Date: August 7, 2008

EX-32

Exhibit 32(a)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, J. Wayne Leonard, Chairman and Chief Executive Officer of Entergy Corporation (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended June 30, 2008 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

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

Date: August 7, 2008

EX-32

Exhibit 32(b)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Leo P. Denault, Executive Vice President and Chief Financial Officer of Entergy Corporation (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended June 30, 2008 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

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

Date: August 7, 2008

EX-32

Exhibit 32(c)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Hugh T. McDonald, Chairman, President and Chief Executive Officer of Entergy Arkansas, Inc. (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended June 30, 2008 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Hugh T. McDonald
Hugh T. McDonald
Chairman, President, and Chief Executive Officer
of Entergy Arkansas, Inc.

Date: August 7, 2008

EX-32

Exhibit 32(d)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I,Jay A. Lewis, Vice President and Chief Financial Officer of Entergy Arkansas, Inc. (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended June 30, 2008 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Arkansas, Inc.

Date: August 7, 2008

EX-32

Exhibit 32(e)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I,E. Renae Conley, Chair of the Board, President and Chief Executive Officer of Entergy Gulf States Louisiana, L.L.C. (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended June 30, 2008 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ E. Renae Conley
E. Renae Conley
Chair of the Board, President and Chief Executive Officer of
Entergy Gulf States Louisiana, L.L.C.

Date: August 7, 2008

EX-32

Exhibit 32(f)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I,Jay A. Lewis, Vice President and Chief Financial Officer of Entergy Gulf States Louisiana, L.L.C. (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended June 30, 2008 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Gulf States Louisiana, L.L.C.

Date: August 7, 2008

EX-32

Exhibit 32(g)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I,E. Renae Conley, Chair of the Board, President and Chief Executive Officer of Entergy Louisiana, LLC (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended June 30, 2008 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ E. Renae Conley
E. Renae Conley
Chair of the Board, President,
and Chief Executive Officer of Entergy Louisiana, LLC

Date: August 7, 2008

EX-32

Exhibit 32(h)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I,Jay A. Lewis, Vice President and Chief Financial Officer of Entergy Louisiana, LLC (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended June 30, 2008 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Louisiana, LLC

Date: August 7, 2008

EX-32

Exhibit 32(i)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Haley R. Fisackerly, Chairman of the Board, President and Chief Executive Officer of Entergy Mississippi, Inc. (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended June 30, 2008 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Haley R. Fisackerly
Haley R. Fisackerly
Chairman of the Board, President, and Chief Executive
Officer of Entergy Mississippi, Inc.

Date: August 7, 2008

EX-32

Exhibit 32(j)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I,Jay A. Lewis, Vice President and Chief Financial Officer of Entergy Mississippi, Inc. (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended June 30, 2008 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Mississippi, Inc.

Date: August 7, 2008

EX-32

Exhibit 32(k)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Roderick K. West, Chairman, President and Chief Executive Officer of Entergy New Orleans, Inc. (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended June 30, 2008 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Roderick K. West
Roderick K. West
Chairman, President and Chief Executive Officer of
Entergy New Orleans, Inc.

Date: August 7, 2008

EX-32

Exhibit 32(l)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I,Jay A. Lewis, Vice President and Chief Financial Officer of Entergy New Orleans, Inc. (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended June 30, 2008 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy New Orleans, Inc.

Date: August 7, 2008

EX-32

Exhibit 32(m)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Joseph F. Domino, Chairman, President and Chief Executive Officer of Entergy Texas, Inc. (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended June 30, 2008 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Joseph F. Domino
Joseph F. Domino
Chairman, President, and Chief Executive Officer
of Entergy Texas, Inc.

Date: August 7, 2008

EX-32

Exhibit 32(n)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I,Jay A. Lewis, Vice President and Chief Financial Officer of Entergy Texas, Inc. (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended June 30, 2008 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Jay A. Lewis
Jay A. Lewis
Vice President and Chief Financial Officer of
Entergy Texas, Inc.

Date: August 7, 2008

EX-32

Exhibit 32(o)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Michael R. Kansler, Chairman, President and Chief Executive Officer of System Energy Resources, Inc. (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended June 30, 2008 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Michael R. Kansler
Michael R. Kansler
Chairman, President, and Chief Executive Officer of
System Energy Resources, Inc.

Date: August 7, 2008

EX-32

Exhibit 32(p)

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Wanda C. Curry, Vice President and Chief Financial Officer of System Energy Resources, Inc. (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended June 30, 2008 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Wanda C. Curry
Wanda C. Curry
Vice President and Chief Financial Officer
of System Energy Resources, Inc.

Date: August 7, 2008