8-K

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C.  20549

FORM 8-K

CURRENT REPORT

Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

Date of Report (Date earliest event reported) June 18, 2012

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	0-05807	ENTERGY NEW ORLEANS, INC. (a Louisiana corporation) 1600 Perdido Street New Orleans, Louisiana 70112 Telephone (504) 670-3700 72-0273040
0-20371	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	1-34360	ENTERGY TEXAS, INC. (a Texas corporation) 350 Pine Street Beaumont, Texas 77701 Telephone (409) 981-2000 61-1435798
1-32718	ENTERGY LOUISIANA, LLC (a Texas limited liability company) 446 North Boulevard Baton Rouge, Louisiana 70802 Telephone (800) 368-3749  75-3206126	1-09067	SYSTEM ENERGY RESOURCES, INC. (an Arkansas corporation) Echelon One 1340 Echelon Parkway Jackson, Mississippi 39213 Telephone (601) 368-5000 72-0752777

____________________________________________________________________________________________

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2.):

[ ]      Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

[ ]      Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

    [ ]       Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

[ ]      Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Item 7.01 Regulation FD Disclosure.

On June 18, 2012, Entergy Corporation published on its website the 2011 Entergy Statistical Report and Investor Guide (the “Report”).  This Report is a compilation of financial and operating data, financial metrics and other information about Entergy and its subsidiaries.  The Report is attached hereto as Exhibit 99.1 and is incorporated herein by reference.  The information contained in this Current Report on Form 8-K is being furnished, not filed, pursuant to Regulation FD.

Item 9.01 Financial Statements and Exhibits.

(d)  Exhibits.

Exhibit No.	Description
99.1	2011 Entergy Statistical Report and Investor Guide

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

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.

By:  /s/ Alyson M. Mount

Alyson M. Mount

Senior Vice President and

Chief Accounting Officer

Dated: June 18, 2012

EX-99.1

ENTERGY STATISTICAL REPORT

AND INVESTOR GUIDE

2011

Entergy is a point-of-view-driven company with a sustainable approach to business. We use sophisticated analyses to develop informed points of view on key issues that affect our business. Our points of view are dynamic, changing with market conditions, and they determine our strategies. We also consider sustainability when setting our strategies by evaluating and optimizing their safety, economic, environmental and societal impact. We believe we must make progress simultaneously along multiple dimensions to truly succeed for all our stakeholders. We have assembled the statistics and facts in this report to support your review and analysis of Entergy’s results over the last five years. This information is available in two electronic files, Excel and PDF in order to facilitate easier access and analysis.

Entergy Investor Relations

Entergy Corporation is an integrated energy company engaged primarily in electric power production and retail distribution operations. Entergy owns and operates power plants with approximately 30,000 megawatts of electric generating capacity, and it is the second-largest nuclear generator in the United States. Entergy delivers electricity to 2.8 million utility customers in Arkansas, Louisiana, Mississippi and Texas. Entergy has annual revenues of more than $11 billion and approximately 15,000 employees.

TABLE OF CONTENTS

	Excel Tab
ABOUT THIS PUBLICATION		Page 2
FORWARD-LOOKING INFORMATION		Page 2
FINANCIAL MEASURES		Page 2
ENTERGY AT A GLANCE		Pages 3 – 4
EXECUTIVE PROFILES		Pages 5 – 6
ENTERGY CORPORATION AND SUBSIDIARIES
Selected Financial and Operating Data		Page 7
Selected Financial Data		Page 7
Utility Electric Operating Data		Page 7
Entergy Wholesale Commodities Operating Data		Page 7
Employees		Page 7
Owned and Leased Capability		Page 7
Consolidated Quarterly Financial Metrics		Page 8
Consolidated Annual Financial Metrics		Page 8
Consolidated Financial Results		Page 9
Consolidated Quarterly Results		Page 9
Consolidated Quarterly Special Items		Page 10
Consolidated Annual Results		Page 11
Consolidated Annual Special Items		Page 12
Description of Consolidated Special Items		Page 13
Consolidated Statements of Income		Page 14
Consolidating Income Statement		Page 15
Consolidated Balance Sheets		Pages 16 – 17
Consolidating Balance Sheet		Pages 18 – 19
Consolidated Statements of Cash Flow		Pages 20 – 21
Cash Flow Information by Business		Page 21
Consolidated Statements of Changes in Equity and Comprehensive Income		Page 22
Consolidated Statements of Comprehensive Income		Page 23
Consolidated Capital Expenditures		Page 24
Entergy Corporation Securities Detail		Page 24
Entergy Corporation Long-Term Debt		Page 24
Securities Ratings (Outlook)		Page 24
UTILITY
Utility Quarterly Financial Metrics		Page 25
Utility Annual Financial Metrics		Page 25
Utility Securities Ratings (Outlook)		Page 25
Utility Historical Capital Expenditures		Page 25
Utility Planned Capital Expenditures		Page 26
Utility Financial Results		Page 26
Utility Consolidating Income Statement		Page 26
Utility Consolidating Balance Sheet		Pages 27 – 28
Utility Selected Annual Financial Metrics		Pages 29 – 31

Note: The Excel Tab labels correspond to the page numbers in the PDF version of the 2011 Statistical Report.

	Excel Tab
UTILITY SECURITIES DETAIL		Page 32
Utility Long-Term Debt and Preferred Stock		Page 32
Entergy Arkansas, Inc.		Page 32
Entergy Gulf States Louisiana, L.L.C.		Page 33
Entergy Louisiana, LLC		Page 34
Entergy Mississippi, Inc.		Page 35
Entergy New Orleans, Inc.		Page 35
Entergy Texas, Inc.		Page 36
System Energy Resources, Inc.		Page 36
UTILITY STATISTICAL INFORMATION		Page 37
Utility Total Capability		Page 37
Utility Selected Operating Data		Page 37
Utility Consolidating Information		Page 38
Entergy Arkansas, Inc.		Pages 39 – 40
Entergy Gulf States Louisiana, L.L.C.		Pages 41 and 43
Entergy Texas, Inc.		Pages 42 – 43
Entergy Louisiana, LLC		Pages 44 – 45
Entergy Mississippi, Inc.		Pages 46 – 47
Entergy New Orleans, Inc.		Pages 48 – 49
System Energy Resources, Inc.		Page 49
Utility Nuclear Plant Statistics		Page 50
UTILITY REGULATORY INFORMATION		Page 51
Regulatory Commissions		Page 51
Commission/Council Members		Page 51
Select Utility Regulatory Mechanisms		Page 52
Utility Electric and Gas Fuel Recovery Mechanisms		Page 53
ENTERGY WHOLESALE COMMODITIES
EWC Quarterly Financial Metrics		Page 54
EWC Annual Financial Metrics		Page 54
EWC Quarterly Operational Metrics		Page 54
EWC Annual Operational Metrics		Page 54
EWC Total Capacity		Page 54
EWC Nuclear Plant Statistics		Page 55
EWC Non-Nuclear Wholesale Assets Plant Statistics		Page 55
EWC Non-Nuclear Wholesale Assets Plant Emissions		Page 55
EWC Nuclear Securities Detail		Page 56
EWC Non-Nuclear Wholesale Assets Securities Detail		Page 56
DEFINITIONS OF OPERATIONAL MEASURES AND GAAP AND NON-GAAP FINANCIAL MEASURES		Page 57
REG G RECONCILIATIONS
Pro Forma Financial Results		Page 58
Financial Measures		Pages 59 – 70
INVESTOR INFORMATION		Page 71

ABOUT THIS PUBLICATION

This publication is unaudited and should be used in conjunction with Entergy’s 2011 Annual Report to Shareholders and Form 10-K filed with the Securities and Exchange Commission. It has been prepared for information purposes and is not intended for use in connection with any sale or purchase of, or any offer to buy, any securities of Entergy Corporation or its subsidiaries.

FORWARD-LOOKING INFORMATION

In this report and from time to time, Entergy Corporation makes statements concerning its expectations, beliefs, plans, objectives, goals, strategies, and future events or performance. Such statements are “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. Words such as “may,” “will,” “could,” “project,” “believe,” “anticipate,” “intend,” “expect,” “estimate,” “continue,” “potential,” “plan,” “predict,” “forecast,” and other similar words or expressions are intended to identify forward-looking statements but are not the only means to identify these statements. Although Entergy 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 report and speaks only as of the date on which such statement is made. Except to the extent required by the federal securities laws, Entergy undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events, or otherwise.

Forward-looking statements involve a number of risks and uncertainties. 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 2011 Form 10-K, (b) Management’s Financial Discussion and Analysis in the 2011 Form 10-K, and (c) the following factors (in addition to others described elsewhere in this report and in subsequent securities filings):

• resolution of pending and future rate cases and negotiations, including various performance-based rate discussions, Entergy’s utility supply plan, and recovery of fuel and purchased power costs

• the termination of Entergy Arkansas’s and Entergy Mississippi’s participation in the System Agreement in December 2013 and November 2015, respectively

• regulatory and operating challenges and uncertainties associated with the Utility operating companies’ proposal to move to the Midwest Independent Transmission System Operator, Inc. regional transmission organization, the operations of the independent coordinator of transmission for Entergy’s utility service territory, and the scheduled expiration of the current independent coordinator of transmission arrangement in November 2012

• risks associated with the proposed spin-off and subsequent merger of Entergy’s electric transmission business into a subsidiary of ITC Holdings Corp., including the risk that Entergy and the Utility operating companies may not be able to timely satisfy the conditions or obtain the approvals required to complete such transaction or such approvals may contain material restrictions or conditions, and the risk that if completed, the transaction may not achieve its anticipated results

• 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, and the application of more stringent transmission reliability requirements or market power criteria by the Federal Energy Regulatory Commission (FERC)

• changes in regulation of nuclear generating facilities and nuclear materials and fuel, including possible shutdown of nuclear generating facilities, particularly those owned or operated by the Entergy Wholesale Commodities business, and the effects of new or existing safety concerns regarding nuclear power plants and nuclear fuel

• resolution of pending or future applications, and related regulatory proceedings and litigation, for license renewals or modifications of nuclear generating facilities

• the performance of and deliverability of power from Entergy’s generation resources, including 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 merchant generating facilities and the ability to hedge, sell power forward or otherwise

reduce the market price risk associated with those facilities, including the Entergy Wholesale Commodities nuclear plants

• the prices and availability of fuel and power Entergy must purchase for its Utility customers, and Entergy’s ability to meet credit support requirements for fuel and power supply contracts

• volatility and changes in markets for electricity, natural gas, uranium, and other energy-related commodities

• changes in law resulting from federal or state energy legislation or legislation subjecting energy derivatives used in hedging and risk management transactions to governmental regulation

• changes in environmental, tax, and other laws, including requirements for reduced emissions of sulfur, nitrogen, carbon, mercury, and other substances, and changes in costs of compliance with environmental and other laws and regulations

• 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, ice storms, or other weather events and the recovery of costs associated with restoration, including accessing funded storm reserves, federal and local cost recovery mechanisms, securitization, and insurance

• effects of climate change

• Entergy’s ability to manage its capital projects and operation and maintenance costs

• Entergy’s ability to purchase and sell assets at attractive prices and on other attractive terms

• the economic climate, and particularly economic conditions in Entergy’s Utility service territory and the Northeast United States and events that could influence economic conditions in those areas

• the effects of Entergy’s strategies to reduce tax payments

• changes in the financial markets, particularly those affecting the availability of capital and Entergy’s ability to refinance existing debt, execute share repurchase programs, and fund investments and acquisitions

• actions of rating agencies, including changes in the ratings of debt and preferred stock, changes in general corporate ratings, and changes in the rating agencies’ ratings criteria

• changes in inflation and interest rates

• the effect of litigation and government investigations or proceedings

• advances in technology

• the potential effects of threatened or actual terrorism, cyber attacks or data security breaches, and war or a catastrophic event such as a nuclear accident or a natural gas pipeline explosion

• Entergy’s ability to attract and retain talented management and directors

• changes in accounting standards and corporate governance

• declines in the market prices of marketable securities and resulting funding requirements for Entergy’s defined benefit pension and other postretirement benefit plans

• changes in decommissioning trust fund values or earnings or in the timing of or cost to decommission nuclear plant sites

• factors that could lead to impairment of long-lived assets

• the ability to successfully complete merger, acquisition, or divestiture plans, regulatory or other limitations imposed as a result of merger, acquisition, or divestiture, and the success of the business following a merger, acquisition, or divestiture

FINANCIAL MEASURES

Financial performance measures shown in this report include those calculated and presented in accordance with generally accepted accounting principles (GAAP), as well as those that are considered non-GAAP measures. This report includes non-GAAP measures of operational earnings, operational adjusted EBITDA, operational return on average invested capital, operational return on average common or members’ equity, operational net margin, operational price to earnings ratio and operational common dividend payout ratio, as well as gross liquidity, debt to capital, excluding securitization debt, net debt to net capital, excluding securitization debt, net debt to net capital with off-balance sheet liabilities, excluding securitization debt, and pro forma financial results and financial measures (average common equity, return on average common equity, debt to capital ratio, cash flow interest coverage) reflecting the jurisdictional separation of Entergy Gulf States, Inc. into Entergy Gulf States Louisiana, L.L.C. and Entergy Texas, Inc., when describing Entergy’s results of operations and financial performance. We have prepared reconciliations of these measures to the most directly comparable GAAP measures. Reconciliations can be found on pages 9, 11, and 58 – 70.

2

ENTERGY AT A GLANCE

CORPORATE STRUCTURE

CORPORATE PROFILE

Entergy Corporation is a Fortune 500 integrated energy company engaged primarily in electric power production and retail distribution operations.

• Approximately 30,000 MW electric generating capacity

• 2nd-largest U.S. nuclear generator

• 2.8 million utility customers

• More than $11 billion annual revenues

• Approximately 15,000 employees

• 96 electric generating units operated

BUSINESS SEGMENTS

Entergy’s five year results in this report are presented in three business segments:

• Utility

• Entergy Wholesale Commodities

• Parent and Other

On December 5, 2011, Entergy Corporation and ITC Holdings Corp. announced that the Boards of Directors of both companies had approved a definitive agreement under which Entergy will spin off and then merge its electric transmission business with ITC. Completion of the transaction is expected in 2013, subject to the satisfaction of certain closing conditions. Primary filings and approvals required include: Entergy’s Retail Regulators, Federal Energy Regulatory Commission, Hart-Scott-Rodino Act, Internal Revenue Service, Securities and Exchange Commission, and ITC Shareholders.

3

ENTERGY CORPORATION AND SUBSIDIARIES BUSINESS SEGMENTS (CONTINUED)

UTILITY

Entergy’s utility companies generate, transmit, distribute, and sell electric power, and operate a small natural gas distribution business.

• Six electric utilities with 2.8 million customers

• Four states – Arkansas, Louisiana, Mississippi, Texas

• 21,000 MW generating capacity

• Two gas utilities with 193,000 customers

ENTERGY ARKANSAS, INC. (EAI)

Entergy Arkansas generates, transmits, distributes, and sells electric power to 693,000 retail customers in portions of Arkansas.

ENTERGY GULF STATES LOUISIANA, L.L.C. (EGSL)^(a)

Entergy Gulf States Louisiana generates, transmits, distributes, and sells electric power to 384,000 retail customers in portions of Louisiana. Entergy Gulf States Louisiana also provides natural gas utility service to 92,000 customers in the Baton Rouge, Louisiana area.

ENTERGY LOUISIANA, LLC (ELL)

Entergy Louisiana generates, transmits, distributes, and sells electric power to 669,000 retail customers in portions of Louisiana.

ENTERGY MISSISSIPPI, INC. (EMI)

Entergy Mississippi generates, transmits, distributes, and sells electric power to 437,000 retail customers in portions of Mississippi.

ENTERGY NEW ORLEANS, INC. (ENOI)

Entergy New Orleans generates, transmits, distributes, and sells electric power to 161,000 retail customers in the city of New Orleans, Louisiana. Entergy New Orleans also provides natural gas utility service to 101,000 customers in the city of New Orleans.

ENTERGY TEXAS, INC. (ETI)^(a)

Entergy Texas generates, transmits, distributes, and sells electric power to 413,000 retail customers in portions of Texas.

SYSTEM ENERGY RESOURCES, INC. (SERI)

System Energy owns or leases 90 percent of the Grand Gulf 1 nuclear generating facility. System Energy sells power and capacity from Grand Gulf 1 at wholesale to Entergy Arkansas (36%), Entergy Louisiana (14%), Entergy Mississippi (33%), and Entergy New Orleans (17%).

UTILITY NUCLEAR PLANTS

Entergy owns and operates five nuclear units at four plant sites to serve its regulated utility business: Arkansas Nuclear One (ANO) Units 1 and 2 near Russellville, Arkansas; Grand Gulf Nuclear Station in Port Gibson, Mississippi; River Bend Station in St. Francisville, Louisiana; and Waterford 3 in Taft, Louisiana.

ENTERGY WHOLESALE COMMODITIES

Entergy’s Wholesale Commodities business owns and operates six nuclear units in the northern United States. This business is focused on selling power produced by those plants to wholesale customers. Entergy’s Wholesale Commodities business also owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. This business also provides services to other nuclear power plant owners.

• 5,011 MW nuclear-owned generating capacity in six units in northern U.S.

• Pilgrim Nuclear Station in Plymouth, Massachusetts

• James A. FitzPatrick in Oswego, New York

• Indian Point Units 2 and 3 in Buchanan, New York

• Vermont Yankee in Vernon, Vermont

• Palisades Nuclear Energy Plant in South Haven, Michigan

• 1,601 net MW non-nuclear generating capacity as of 12/31/2011

• 800 MW under management services contract

• Cooper Nuclear Station located near Brownville, Nebraska

• Contracts (ongoing and completed) with other nuclear facility owners to provide decommissioning and license renewal services

(a) 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, Inc., and the other operating under the sole retail jurisdiction of the LPSC, Entergy Gulf States Louisiana, L.L.C., Entergy Gulf States Louisiana, L.L.C. is the successor for financial reporting purposes to Entergy Gulf States, Inc.

4

ENTERGY CORPORATION AND SUBSIDIARIES EXECUTIVE PROFILES

WAYNE LEONARD – CHAIRMAN AND CHIEF EXECUTIVE OFFICER

Wayne Leonard became Entergy’s chairman and chief executive officer on August 1, 2006 after serving as chief executive officer since January 1, 1999. Leonard joined Entergy in April 1998 as president and chief operating officer of the company’s domestic business, and he assumed additional responsibility for international operations in August 1998. Over Leonard’s thirteen-year tenure as chief executive officer, Entergy’s overall performance, as measured by total shareholder return, ranked top quartile in the Philadelphia Utility Index. For ten consecutive years, Entergy has been included on the Dow Jones Sustainability World Index or the DJSI North America Index or both. Institutional Investor magazine ranked Leonard the top CEO in the power industry and Entergy the top electric utility in the country in 2010. In 2008, Entergy received a Platts Award of Excellence for its standout performance year after year over the past decade. In 2002 and 2005 Entergy was honored to receive the electric power industry’s highest honor, the Edison Award, from the Edison Electric Institute. The Platts Global Energy Awards named Leonard 2003 CEO of the Year and Leonard has been a CEO of the Year finalist for an unprecedented 11 consecutive years. Prior to joining Entergy, Leonard was president of Cinergy’s Energy Commodities Strategic Business Unit and president of Cinergy Capital Trading.

LEO DENAULT – EXECUTIVE VICE PRESIDENT AND CHIEF FINANCIAL OFFICER

Leo Denault became executive vice president and chief financial officer in February 2004. He is responsible for corporate-wide finance, accounting, tax, internal audit, treasury, investor relations, corporate development and planning activities, as well as information technology. Denault was named to Institutional Investor magazine’s “2010 All-America Executive Team” and was ranked as the best CFO in the power industry in 2010 and 2009. Denault was previously vice president of corporate development and strategic planning. Denault joined Entergy in March 1999 as vice president, corporate development and assumed expanded responsibility for the areas of strategic planning, investment analysis and risk management. Prior to joining Entergy, Denault was vice president of corporate development at Cinergy Corporation, where he reviewed every major investment transaction, including the acquisition of generation, distribution and trading businesses in the United States and abroad.

ROD WEST – EXECUTIVE VICE PRESIDENT AND CHIEF ADMINISTRATIVE OFFICER

Rod West became executive vice president and chief administrative officer in June 2010. He is responsible for the office of general counsel, human resources and administration, federal regulatory and governmental affairs, public policy and corporate communications organizations. West previously served as president and chief executive officer of Entergy New Orleans, Inc. after serving as director of electric distribution operations. During his tenure at Entergy New Orleans, West was credited with managing the rebuild of critical aspects of the New Orleans infrastructure after Hurricane Katrina, and for leading Entergy New Orleans out of bankruptcy after the storm. Prior to joining Entergy in April 1999 as senior regulatory counsel, West was senior attorney in the New Orleans office of Vial, Hamilton, Koch and Knox, L.L.P., having previously spent five years with the New Orleans-based firm of Jones, Walker, Waechter, Poitevent, Carrere & Denegre, L.L.P.

RICK SMITH – PRESIDENT, ENTERGY WHOLESALE COMMODITIES BUSINESS

Rick Smith became president of Entergy’s Wholesale Commodities business in June 2010. His organization is aimed at strengthening local regulatory presence in the Northeast and consolidating commercial and risk functions for Entergy’s Wholesale Commodities business associated with non-utility generation. Smith previously served as president and chief operating officer from April 2007 until June 2010. Prior to being named president and COO, Smith was group president of utility operations. Smith joined Entergy in September 1999 as senior vice president, transition management and later served as president of retail operations. Prior to joining Entergy, Smith was president of Cinergy Resources, Inc., a non-regulated retail supply business. Prior to that, he served for three years as vice president of finance for Cinergy’s Energy Services business unit.

THEO BUNTING – GROUP PRESIDENT, UTILITY OPERATIONS

Theo Bunting became group president, utility operations in May 2012. He is responsible for the regulated utility financial results, along with operational results of electric and natural gas distribution and customer service. In addition, Bunting oversees utility regulatory support and regulated retail activities. Prior to his current role, Bunting served as senior vice president and chief accounting officer for Entergy Corporation and its subsidiaries. While at Entergy, he has served as vice president, chief financial officer – Nuclear Operations; vice president, chief financial officer – System Energy Resources, Inc.; vice president, chief financial officer – operations; and vice president, and chief financial officer for the five utility subsidiaries. Bunting began his career in public accounting with Arthur Andersen & Co. in 1981. He joined Entergy Arkansas in 1983 and rejoined Entergy in 1999 after having been co-founder and partner in a utility consulting business.

MARK SAVOFF – EXECUTIVE VICE PRESIDENT AND CHIEF OPERATING OFFICER

Mark Savoff became chief operating officer in June 2010. He is responsible for nuclear operations as well as the business operations of fossil generation, transmission operations, system safety and environment, supply chain, system planning, and performance management. He is also responsible for driving several key initiatives within the company: safety, compliance (including critical infrastructure protection), environmental policy (climate change), generation portfolio transformation and Entergy Continuous Improvement. Prior to being named COO, he served as executive vice president of operations, a position he held since joining the company in December 2003. Prior to joining Entergy, Savoff was vice president and corporate officer at GE Power Systems, Nuclear Energy. Before assuming his role as vice president, Nuclear Energy, he was General Manager of GE’s global nuclear fuel business. He also served as president, Reuter-Stokes, a GE subsidiary.

JOHN HERRON – PRESIDENT, CEO & CHIEF NUCLEAR OFFICER

John Herron became president, CEO, and chief nuclear officer of Entergy Nuclear in December 2009. He is responsible for all of Entergy’s nuclear plants located throughout New York, Massachusetts, Vermont, Michigan, Louisiana, Mississippi and Arkansas, as well as management of the Cooper Nuclear Station for the State of Nebraska. Herron was previously senior vice president for nuclear operations. Herron joined Entergy in 2001 as vice president, operations at Waterford 3. He became senior vice president of Indian Point in February 2002. Herron began his career in nuclear operations in 1979 at Vermont Yankee. In 1994, he became plant manager at Cooper Nuclear Station. He then joined Tennessee Valley Authority as plant manager at Sequoyah Nuclear Plant and then site vice president at TVA’s Browns Ferry Nuclear Plant.

5

ENTERGY CORPORATION AND SUBSIDIARIES EXECUTIVE PROFILES (CONTINUED)

MARCUS BROWN – SENIOR VICE PRESIDENT AND GENERAL COUNSEL

Marcus Brown became senior vice president and general counsel in January 2012. He is responsible for all internal and outside counsel, providing legal advice and counsel to all subsidiaries of Entergy Corporation. Brown previously served as vice president and deputy general counsel. He led the efforts to recover more than $500 million in insurance proceeds that was critical to rebuilding Entergy’s electric and gas infrastructure following Hurricanes Katrina, Rita and Ike. Brown supported Entergy New Orleans, Inc.’s successful emergence from bankruptcy. Recently, he led the legal team’s successful challenge to several Vermont statutes impacting the future operations of the Vermont Yankee nuclear plant. Prior to joining Entergy in 1995, Brown was an associate attorney in the New Orleans-based Stone Pigman law firm, concentrating his practice in commercial litigation, copyright and trademark protection, and constitutional law.

RENAE CONLEY – EXECUTIVE VICE PRESIDENT, HUMAN RESOURCES AND ADMINISTRATION

Renae Conley became executive vice president, human resources and administration in January 2011. She is also Entergy’s chief diversity and inclusion officer and a member of the office of the chief executive. Conley previously served as president and chief executive officer of Entergy’s Louisiana utilities between 2000 and 2010. Entergy Louisiana and Entergy Gulf States Louisiana together serve over one million customers, and comprise the largest electric utility in the state. Prior to joining Entergy in 1999 as vice president of investor relations, Conley was president of Cincinnati Gas & Electric Company, a subsidiary of Cinergy Corp. Conley also served as president and CEO of Cadence, a joint venture of Cinergy and other utilities that provides energy management services.

ENTERGY CORPORATION AND SUBSIDIARIES UTILITY OPERATING COMPANY PRESIDENTS

HALEY FISACKERLY – PRESIDENT & CEO, ENTERGY MISSISSIPPI

Haley Fisackerly became president and CEO of Entergy Mississippi in June 2008. He is responsible for Entergy Mississippi’s electric distribution system, customer service, economic development, regulatory and governmental affairs. Prior to being named president, Fisackerly was vice president of governmental and regulatory affairs for Entergy Nuclear. Prior to that, he was Entergy Mississippi’s vice president of customer operations. Fisackerly joined Entergy in 1995 in federal governmental affairs in Washington D.C. and later moved to Little Rock, AR, where he was director of system regulatory strategy. Prior to joining Entergy, Fisackerly served for several years on the staff of U.S. Senator Thad Cochran.

HUGH McDONALD – PRESIDENT & CEO, ENTERGY ARKANSAS

Hugh McDonald became president and CEO of Entergy Arkansas in 2000. He is responsible for Entergy Arkansas’ electric distribution system, customer service, economic development, regulatory and governmental affairs. Prior to becoming president, he led Entergy’s Retail Operations. McDonald joined Entergy in 1982 at the Waterford 3 nuclear plant. In 1989, he became executive assistant to the chairman of Entergy Louisiana / Entergy New Orleans and then led Entergy Louisiana’s Total Quality initiative until 1993. During Entergy’s merger with Gulf States Utilities, McDonald served as special projects director for the integration of the transmission, distribution, and customer service organizations. McDonald has also held the positions of division manager, Entergy Mississippi and director of regulatory affairs, Entergy Texas.

BILL MOHL – PRESIDENT & CEO, ENTERGY LOUISIANA LLC AND ENTERGY GULF STATES LOUISIANA L.L.C.

Bill Mohl became president and CEO of Entergy Louisiana and Entergy Gulf States Louisiana in June 2010. He is responsible for the Louisiana utilities’ electric and gas distribution systems, customer service, economic development, regulatory and governmental affairs. He was previously vice president, system planning and operations. Mohl joined Entergy in 2002 where he was responsible for the procurement of all limited- and long-term fuel and generation resources and in 2007 added responsibility for system planning and operations. Mohl began his career at Public Service Company of Colorado, now an affiliate of Xcel Energy, before moving to Koch Industries where he held a number of leadership roles in various gas and power businesses.

SALLIE RAINER – PRESIDENT & CEO, ENTERGY TEXAS

Sallie Rainer became president and CEO of Entergy Texas in May 2012. She is responsible for Entergy Texas’ electric distribution system, customer service, economic development, regulatory and governmental affairs. Prior to being named president, Rainer served as vice president, federal policy. She joined Entergy in 1984, working in the generation planning department. In 1997, she joined the energy management organization in The Woodlands, holding a number of management positions including director, strategic initiatives.

CHARLES RICE – PRESIDENT & CEO, ENTERGY NEW ORLEANS

Charles Rice became president and CEO of Entergy New Orleans in June 2010. He is responsible for Entergy New Orleans’ electric and gas distribution system, customer service, economic development, regulatory and governmental affairs. Rice was previously director of regulatory affairs for Entergy New Orleans. After his first legal private practice position in Louisiana with Jones, Walker, Waechter, Poitevent, Carrere & Denegre, L.L.P, Rice joined Entergy’s legal department in 2000 as senior counsel and then as manager of labor relations litigation support in human resources. Rice was recruited into New Orleans city government in 2002 as the city attorney and later took the role of chief administrative officer for the City of New Orleans. In 2005, Barrasso, Usdin, Kupperman, Freeman & Sarver, L.L.C. recruited him back to private practice, where he was named partner. Returning to Entergy in 2009, Rice served as director of utility strategy, then moved into the director of regulatory affairs position for Entergy New Orleans before being named to his current role.

6

SELECTED FINANCIAL AND OPERATING DATA

SELECTED FINANCIAL DATA

(In millions, except percentages, per share amounts, and ratios)	2011			2010			2009			2008			2007
GAAP MEASURES
Operating Revenues	$	11,229		$	11,488		$	10,746		$	13,094		$	11,484
As-Reported Net Income	$	1,346		$	1,250		$	1,231		$	1,221		$	1,135
As-Reported Earnings Per Share	$	7.55		$	6.66		$	6.30		$	6.20		$	5.60
Shares of Common Stock Outstanding:
End of Year		176.4			178.7			189.1			189.4			193.1
Weighted Average – Diluted		178.4			187.8			195.8			201.0			202.8
Return on Average Invested Capital – As-Reported		8.0	%		7.8	%		7.7	%		8.1	%		8.3	%
Return on Average Common Equity – As-Reported		15.4	%		14.6	%		14.9	%		15.4	%		14.1	%
Net Cash Flow Provided by Operating Activities	$	3,129		$	3,926		$	2,933		$	3,324		$	2,560
Year-End Closing Market Price Per Share of Common Stock	$	73.05		$	70.83		$	81.84		$	83.13		$	119.52
Book Value Per Share at End of Year	$	50.81		$	47.53		$	45.54		$	42.07		$	40.71
Market Value of Equity at End of Year	$	12,883		$	12,661		$	15,477		$	15,741		$	23,082
Price to Earnings Ratio – As-Reported		9.68			10.64			12.99			13.41			21.34
Common Dividend Paid Per Share	$	3.32		$	3.24		$	3.00		$	3.00		$	2.58
Common Dividend Payout Ratio – As-Reported		44	%		49	%		48	%		48	%		46	%
NON-GAAP MEASURES
Operational Earnings	$	1,359		$	1,332		$	1,302		$	1,276		$	1,167
Operational Earnings Per Share	$	7.62		$	7.10		$	6.67		$	6.51		$	5.76
Special Items Per Share	$	(0.07	)	$	(0.44	)	$	(0.37	)	$	(0.31	)	$	(0.16	)
Return on Average Invested Capital – Operational		8.0	%		8.2	%		8.1	%		8.4	%		8.5	%
Return on Average Common Equity – Operational		15.6	%		15.6	%		15.7	%		16.1	%		14.5	%
Price to Earnings Ratio – Operational		9.59			9.98			12.27			12.77			20.75
Common Dividend Payout Ratio – Operational		44	%		46	%		45	%		46	%		45	%
UTILITY ELECTRIC OPERATING DATA
	2011			2010			2009			2008			2007
Retail Kilowatt-Hour Sales (millions)		108,688			107,510			99,148			100,609			102,013
Peak Demand (megawatts)		22,387			21,799			21,009			21,241			22,001
Retail Customers – Year End (thousands)		2,757			2,743			2,719			2,689			2,668
ENTERGY WHOLESALE COMMODITIES OPERATING DATA
	2011			2010			2009			2008			2007
Operating Revenues (millions)(a)	$	2,414		$	2,566		$	2,711		$	2,794		$	2,247
Billed Electric Energy Sales (gigawatt hours)		43,520			42,682			43,969			44,747			40,916
(a)   Includes revenue associated with below-market PPA for Palisades of $42,996,197 for 2011, $46,296,187 for 2010, $52,520,249 for 2009, $76,223,175 for 2008, and $50,215,623 for 2007.
EMPLOYEES
	2011			2010			2009			2008			2007
Total Employees – Year End		14,682			14,958			15,181			14,669			14,322

OWNED AND LEASED CAPABILITY (MW)^(a)

As of December 31, 2011

	Entergy Arkansas		Entergy Gulf States Louisiana		Entergy Louisiana		Entergy Mississippi		Entergy New Orleans		Entergy Texas		System Energy		Entergy Wholesale Commodities (c)(d)(e)		Total
Gas/Oil		1,534		1,980		4,843		2,632		764		2,269		-		1,340		15,362
Coal		1,209		363		-		420		-		269		-		181		2,442
Total Fossil		2,743		2,343		4,843		3,052		764		2,538		-		1,521		17,804
Nuclear		1,823		974		1,159		-		-		-		1,071		5,011		10,038
Other(b)		74		-		-		-		-		-		-		80		154
Total		4,640		3,317		6,002		3,052		764		2,538		1,071		6,612		27,996

(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.

(b) Other includes Hydro (EAI) and Wind (EWC).

(c) Reflects Net MW in Operation. Net MW in Operation is the installed capacity owned and operated. Excludes management services contract for Cooper Nuclear Station.

(d) Reflects the final testing and confirmation of a small incremental increase in output associated with equipment replacements installed at Palisades.

(e) Reflects nameplate rating of generating unit and excludes capacity under contract.

7

CONSOLIDATED ENTERGY CORPORATION AND SUBSIDIARIES DATA

CONSOLIDATED QUARTERLY FINANCIAL METRICS

	2011										2010										YTD %
	1Q		2Q		3Q		4Q		YTD		1Q		2Q		3Q		4Q		YTD		CHANGE
GAAP MEASURES
As-Reported Net Income ($ millions)		248.7		315.6		628.1		154.1		1,346.4		213.8		315.3		492.9		228.3		1,250.2		7.7
Return on Average Invested Capital – As-Reported (%)(a)		7.7		7.7		8.2		8.0		8.0		7.6		8.1		8.2		7.8		7.8		2.6
Return on Average Common Equity – As-Reported (%)(a)		14.8		14.8		16.1		15.4		15.4		13.8		14.8		15.5		14.6		14.6		5.5
Net Margin – As-Reported (%)(a)		11.4		11.5		12.6		12.0		12.0		11.3		11.7		11.7		10.9		10.9		10.1
Cash Flow Interest Coverage (# times)(a)		7.8		7.6		6.6		7.1		7.1		6.3		6.6		8.0		7.8		7.8		(9.0	)
Revolver Capacity ($ millions)		2,258		1,993		2,116		2,001		2,001		1,417		1,338		2,216		2,354		2,354		(15.0	)
Total Debt ($ millions)		12,018		12,360		12,452		12,387		12,387		12,152		11,853		12,247		11,816		11,816		4.8
Debt to Capital Ratio (%)		57.6		58.1		57.3		57.3		57.3		57.0		56.6		57.5		57.3		57.3		-
Off-Balance Sheet Liabilities ($ millions)		650		647		645		604		604		644		641		638		653		653		(7.5	)
NON-GAAP MEASURES
Operational Earnings ($ millions)		248.7		315.6		628.1		167.2		1,359.5		253.7		325.7		518.1		235.0		1,332.5		2.0
Return on Average Invested Capital – Operational (%)(a)		7.9		7.9		8.2		8.0		8.0		8.0		8.5		8.7		8.2		8.2		(2.4	)
Return on Average Common Equity – Operational (%)(a)		15.3		15.2		16.1		15.6		15.6		14.9		15.8		16.6		15.6		15.6		-
Net Margin – Operational (%)(a)		11.8		11.8		12.7		12.1		12.1		12.2		12.5		12.5		11.6		11.6		4.3
Total Gross Liquidity ($ millions)		2,984		2,523		3,103		2,695		2,695		3,074		2,674		4,147		3,648		3,648		(26.1	)
Debt to Capital Ratio, Excluding Securitization Debt (%)		55.7		56.3		55.1		55.0		55.0		55.2		54.8		55.6		55.3		55.3		(0.5	)
Net Debt to Net Capital Ratio, Excluding Securitization Debt (%)		54.0		55.1		52.8		53.5		53.5		51.3		51.6		50.9		52.1		52.1		2.7
Net Debt to Net Capital Ratio Including Off-Balance Sheet Liabilities, Excluding Securitization Debt (%)		55.5		56.5		54.3		54.8		54.8		52.9		53.2		52.5		53.8		53.8		1.9

^(a)  Rolling twelve months. Totals may not foot due to rounding.

CONSOLIDATED ANNUAL FINANCIAL METRICS

	2011		2010		2009		2008		2007
GAAP MEASURES
As-Reported Net Income ($ millions)		1,346		1,250		1,231		1,221		1,135
Return on Average Invested Capital – As-Reported (%)		8.0		7.8		7.7		8.1		8.3
Return on Average Common Equity – As-Reported (%)		15.4		14.6		14.9		15.4		14.1
Net Margin – As-Reported (%)		12.0		10.9		11.5		9.3		9.9
Cash Flow Interest Coverage (# times)		7.1		7.8		6.1		6.5		5.0
Revolver Capacity ($ millions)		2,001		2,354		1,464		645		1,730
Total Debt ($ millions)		12,387		11,816		12,014		12,279		11,123
Debt to Capital Ratio (%)		57.3		57.3		57.4		59.7		57.6
Off-Balance Sheet Liabilities ($ millions)
Debt of Joint Ventures – Entergy’s Share		96		107		116		125		135
Leases – Entergy’s Share		508		546		530		449		523
Total		604		653		646		574		658
NON-GAAP MEASURES
Operational Earnings ($ millions)		1,359		1,332		1,302		1,276		1,167
Return on Average Invested Capital – Operational (%)		8.0		8.2		8.1		8.4		8.5
Return on Average Common Equity – Operational (%)		15.6		15.6		15.7		16.1		14.5
Net Margin – Operational (%)		12.1		11.6		12.1		9.7		10.2
Total Gross Liquidity ($ millions)		2,695		3,648		3,174		2,565		2,984
Debt to Capital Ratio, Excluding Securitization Debt (%)		55.0		55.3		55.6		59.1		56.9
Net Debt to Net Capital Ratio, Excluding Securitization Debt (%)		53.5		52.1		51.5		54.8		53.9
Net Debt to Net Capital Ratio Including Off-Balance Sheet Liabilities, Excluding Securitization Debt (%)		54.8		53.8		53.1		56.2		55.5

8

FINANCIAL RESULTS

ENTERGY CORPORATION CONSOLIDATED QUARTERLY RESULTS – GAAP TO NON-GAAP RECONCILIATION

	2011														2010															YTD
($/share)	1Q			2Q		3Q			4Q			YTD			1Q			2Q			3Q			4Q			YTD			CHANGE
AS-REPORTED
Utility		0.91			1.39		2.95			0.96			6.20			0.73			1.18			1.78			0.63			4.33			1.87
Entergy Wholesale Commodities		0.68			0.36		0.73			0.97			2.74			0.47			0.55			0.76			0.83			2.59			0.15
Parent & Other		(0.21	)		0.01		(0.15	)		(1.06	)		(1.39	)		(0.08	)		(0.08	)		0.08			(0.20	)		(0.26	)		(1.13	)
CONSOLIDATED AS-REPORTED EARNINGS		1.38			1.76		3.53			0.87			7.55			1.12			1.65			2.62			1.26			6.66			0.89
LESS SPECIAL ITEMS
Utility		-			-		-			-			-			-			-			-			-			-			-
Entergy Wholesale Commodities		-			-		-			-			-			(0.29	)		(0.08	)		(0.14	)		(0.04	)		(0.54	)		0.54
Parent & Other		-			-		-			(0.07	)		(0.07	)		0.08			0.02			-			-			0.10			(0.17	)
TOTAL SPECIAL ITEMS		-			-		-			(0.07	)		(0.07	)		(0.21	)		(0.06	)		(0.14	)		(0.04	)		(0.44	)		0.37
OPERATIONAL
Utility		0.91			1.39		2.95			0.96			6.20			0.73			1.18			1.78			0.63			4.33			1.87
Entergy Wholesale Commodities		0.68			0.36		0.73			0.97			2.74			0.76			0.63			0.90			0.87			3.13			(0.39	)
Parent & Other		(0.21	)		0.01		(0.15	)		(0.99	)		(1.32	)		(0.16	)		(0.10	)		0.08			(0.20	)		(0.36	)		(0.96	)
CONSOLIDATED OPERATIONAL EARNINGS		1.38			1.76		3.53			0.94			7.62			1.33			1.71			2.76			1.30			7.10			0.52
Weather Impact		0.10			0.18		0.29			(0.05	)		0.52			0.17			0.09			0.29			0.06			0.62			(0.10	)
SHARES OF COMMON STOCK
OUTSTANDING (in millions)
End of Period		178.3			176.8		176.1			176.4			176.4			189.3			187.5			181.5			178.7			178.7			(2.3	)
Weighted Average - Diluted		180.1			178.9		177.7			177.1			178.4			191.3			190.7			187.8			181.6			187.8			(9.4	)

Totals may not foot due to rounding.

9

FINANCIAL RESULTS

ENTERGY CORPORATION CONSOLIDATED QUARTERLY SPECIAL ITEMS (Shown as Positive/(Negative) Impact on Earnings)

	2011												2010															YTD
($/share)	1Q		2Q		3Q		4Q			YTD			1Q			2Q			3Q			4Q			YTD			CHANGE
UTILITY
SPECIAL ITEMS
None		-		-		-		-			-			-			-			-			-			-			-
Total		-		-		-		-			-			-			-			-			-			-			-
ENTERGY WHOLESALE COMMODITIES
SPECIAL ITEMS
Non-utility nuclear spin-off expenses		-		-		-		-			-			(0.29	)		(0.08	)		(0.14	)		(0.04	)		(0.54	)		0.54
Total		-		-		-		-			-			(0.29	)		(0.08	)		(0.14	)		(0.04	)		(0.54	)		0.54
PARENT & OTHER
SPECIAL ITEMS
Non-utility nuclear spin-off expenses		-		-		-		-			-			0.08			0.02			-			-			0.10			(0.10	)
Transmission business spin-merge expenses		-		-		-		(0.07	)		(0.07	)		-			-			-			-			-			(0.07	)
Total		-		-		-		(0.07	)		(0.07	)		0.08			0.02			-			-			0.10			(0.17	)
TOTAL SPECIAL ITEMS		-		-		-		(0.07	)		(0.07	)		(0.21	)		(0.06	)		(0.14	)		(0.04	)		(0.44	)		0.37
	2011												2010															YTD
($ millions)	1Q		2Q		3Q		4Q			YTD			1Q			2Q			3Q			4Q			YTD			CHANGE
UTILITY
SPECIAL ITEMS
None		-		-		-		-			-			-			-			-			-			-			-
Total		-		-		-		-			-			-			-			-			-			-			-
ENTERGY WHOLESALE COMMODITIES
SPECIAL ITEMS
Non-utility nuclear spin-off expenses		-		-		-		-			-			(54.3	)		(14.5	)		(25.2	)		(6.7	)		(100.7	)		100.7
Total		-		-		-		-			-			(54.3	)		(14.5	)		(25.2	)		(6.7	)		(100.7	)		100.7
PARENT & OTHER
SPECIAL ITEMS
Non-utility nuclear spin-off expenses		-		-		-		-			-			14.4			4.0			-			-			18.5			(18.5	)
Transmission business spin-merge expenses		-		-		-		(13.0	)		(13.0	)		-			-			-			-			-			(13.0	)
Total		-		-		-		(13.0	)		(13.0	)		14.4			4.0			-			-			18.5			(31.5	)
TOTAL SPECIAL ITEMS		-		-		-		(13.0	)		(13.0	)		(39.9	)		(10.5	)		(25.2	)		(6.7	)		(82.2	)		69.2
Totals may not foot due to rounding.

10

FINANCIAL RESULTS

ENTERGY CORPORATION CONSOLIDATED ANNUAL RESULTS – GAAP TO NON-GAAP RECONCILIATION

($/share)	2011			2010			2009			2008			2007
AS-REPORTED
Utility		6.20			4.33			3.53			2.92			3.37
Entergy Wholesale Commodities		2.74			2.59			3.26			3.96			2.88
Parent & Other		(1.39	)		(0.26	)		(0.49	)		(0.68	)		(0.65	)
CONSOLIDATED AS-REPORTED EARNINGS		7.55			6.66			6.30			6.20			5.60
LESS SPECIAL ITEMS
Utility		-			-			-			(0.08	)		(0.07	)
Entergy Wholesale Commodities		-			(0.54	)		(0.23	)		(0.10	)		(0.09	)
Parent & Other		(0.07	)		0.10			(0.14	)		(0.13	)		-
TOTAL SPECIAL ITEMS		(0.07	)		(0.44	)		(0.37	)		(0.31	)		(0.16	)
OPERATIONAL
Utility		6.20			4.33			3.53			3.00			3.44
Entergy Wholesale Commodities		2.74			3.13			3.49			4.06			2.97
Parent & Other		(1.32	)		(0.36	)		(0.35	)		(0.55	)		(0.65	)
CONSOLIDATED OPERATIONAL EARNINGS		7.62			7.10			6.67			6.51			5.76
Weather Impact		0.52			0.62			(0.01	)		(0.02	)		0.11

11

FINANCIAL RESULTS

ENTERGY CORPORATION CONSOLIDATED ANNUAL SPECIAL ITEMS (Shown as Positive/(Negative) Impact on Earnings)

($/share)	2011			2010			2009			2008			2007
UTILITY SPECIAL ITEMS
Dilution effect - unsuccessful remarketing		-			-			-			(0.08	)		-
Nuclear alignment		-			-			-			-			(0.07	)
Total		-			-			-			(0.08	)		(0.07	)
ENTERGY WHOLESALE COMMODITIES SPECIAL ITEMS
Non-utility nuclear spin-off expenses		-			(0.54	)		(0.23	)		-			-
Dilution effect - unsuccessful remarketing		-			-			-			(0.10	)		-
Nuclear alignment		-			-			-			-			(0.09	)
Total		-			(0.54	)		(0.23	)		(0.10	)		(0.09	)
PARENT & OTHER SPECIAL ITEMS
Transmission business spin-merge expenses		(0.07	)		-			-			-			-
Non-utility nuclear spin-off expenses		-			0.10			(0.14	)		(0.28	)		-
Dilution effect - unsuccessful remarketing		-			-			-			0.15			-
Total		(0.07	)		0.10			(0.14	)		(0.13	)		-
TOTAL SPECIAL ITEMS		(0.07	)		(0.44	)		(0.37	)		(0.31	)		(0.16	)
($ millions)		2011			2010			2009			2008			2007
UTILITY SPECIAL ITEMS
Nuclear alignment		-			-			-			-			(13.6	)
Total		-			-			-			-			(13.6	)
ENTERGY WHOLESALE COMMODITIES SPECIAL ITEMS
Non-utility nuclear spin-off expenses		-			(100.7	)		(44.0	)		-			-
Nuclear alignment		-			-			-			-			(18.4	)
Total		-			(100.7	)		(44.0	)		-			(18.4	)
PARENT & OTHER SPECIAL ITEMS
Transmission business spin-merge expenses		(13.0	)		-			-			-			-
Non-utility nuclear spin-off expenses		-			18.5			(27.0	)		(55.4	)		-
Total		(13.0	)		18.5			(27.0	)		(55.4	)		-
TOTAL SPECIAL ITEMS		(13.0	)		(82.2	)		(71.0	)		(55.4	)		(32.0	)

12

FINANCIAL RESULTS

DESCRIPTION OF ENTERGY CORPORATION CONSOLIDATED SPECIAL ITEMS

	MAIN EARNINGS CATEGORY
UTILITY SPECIAL ITEMS
Dilution effect – unsuccessful remarketing(a)	Diluted earnings per share
Nuclear alignment	Operating expenses: Other operation and maintenance
ENTERGY WHOLESALE COMMODITIES SPECIAL ITEMS
Non-utility nuclear spin-off expenses	Operating expenses: Other operation and maintenance Operating expenses: Taxes other than income taxes Operating expenses: Depreciation Interest and Other Charges: Other interest
Dilution effect – unsuccessful remarketing(a)	Diluted earnings per share
Nuclear alignment	Operating expenses: Other operation and maintenance
PARENT & OTHER SPECIAL ITEMS
Transmission business spin-merge expenses	Operating expenses: Other operation and maintenance Income taxes
Non-utility nuclear spin-off expenses	Operating expenses: Other operation and maintenance Income taxes
Dilution effect – unsuccessful remarketing(a)	Diluted earnings per share

(a) Entergy had 10,000,000 equity units outstanding as of December 31, 2008, that obligated the holders to purchase a certain number of shares of Entergy common stock for a stated price no later than February 17, 2009. Under the terms of the purchase contracts, Entergy attempted to remarket the notes payable associated with the equity units in February 2009 but was unsuccessful, the note holders put the notes to Entergy, Entergy retired the notes, and Entergy issued 6,598,000 shares of common stock in the settlement of the purchase contracts.

13

FINANCIAL RESULTS

CONSOLIDATED STATEMENTS OF INCOME (unaudited)

In thousands, except share data, for the years ended December 31,	2011			2010			2009			2008			2007
OPERATING REVENUES:
Electric		$8,673,517			$8,740,637			$7,880,016			$10,073,160			$9,046,301
Natural gas		165,819			197,658			172,213			241,856			206,073
Competitive businesses		2,389,737			2,549,282			2,693,421			2,778,740			2,232,024
Total		11,229,073			11,487,577			10,745,650			13,093,756			11,484,398
OPERATING EXPENSES:
Operating and maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		2,492,714			2,518,582			2,309,831			3,577,764			2,934,833
Purchased power		1,564,967			1,659,416			1,395,203			2,491,200			1,986,950
Nuclear refueling outage expenses		255,618			256,123			241,310			221,759			180,971
Other operation and maintenance		2,867,758			2,969,402			2,750,810			2,742,762			2,649,654
Decommissioning		190,595			211,736			199,063			189,409			167,898
Taxes other than income taxes		536,026			534,299			503,859			496,952			489,058
Depreciation and amortization		1,102,202			1,069,894			1,082,775			1,030,860			963,712
Other regulatory charges (credits) – net		205,959			44,921			(21,727	)		59,883			54,954
Total		9,215,839			9,264,373			8,461,124			10,810,589			9,428,030
Gain on sale of business		-			44,173			-			-			-
OPERATING INCOME		2,013,234			2,267,377			2,284,526			2,283,167			2,056,368
OTHER INCOME:
Allowance for equity funds used during construction		84,305			59,381			59,545			44,523			42,742
Interest and investment income		129,134			185,455			236,628			197,872			238,911
Other than temporary impairment losses		(140	)		(1,378	)		(86,069	)		(49,656	)		(4,914	)
Miscellaneous – net		(59,271	)		(48,124	)		(40,396	)		(23,452	)		(21,684	)
Total		154,028			195,334			169,708			169,287			255,055
INTEREST EXPENSE:
Interest expense		551,521			610,146			603,679			634,188			662,084
Allowance for borrowed funds used during construction		(37,894	)		(34,979	)		(33,235	)		(25,267	)		(25,032	)
Total		513,627			575,167			570,444			608,921			637,052
INCOME BEFORE INCOME TAXES		1,653,635			1,887,544			1,883,790			1,843,533			1,674,371
Income taxes		286,263			617,239			632,740			602,998			514,417
CONSOLIDATED NET INCOME		1,367,372			1,270,305			1,251,050			1,240,535			1,159,954
Preferred dividend requirements of subsidiaries		20,933			20,063			19,958			19,969			25,105
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION		$1,346,439			$1,250,242			$1,231,092			$1,220,566			$1,134,849
Basic earnings per average common share		$7.59			$6.72			$6.39			$6.39			$5.77
Diluted earnings per average common share		$7.55			$6.66			$6.30			$6.20			$5.60
Dividends declared per common share		$3.32			$3.24			$3.00			$3.00			$2.58
Average number of common shares outstanding:
Basic		177,430,208			186,010,452			192,772,032			190,925,613			196,572,945
Diluted		178,370,695			187,814,235			195,838,068			201,011,588			202,780,283

Certain prior year data has been reclassified to conform with current year presentation.

14

FINANCIAL RESULTS

2011 CONSOLIDATING INCOME STATEMENT (unaudited)

In thousands, except share data, for the year ended December 31, 2011.	UTILITY			ENTERGY WHOLESALE COMMODITIES			PARENT & OTHER			CONSOLIDATED
OPERATING REVENUES:
Electric	$	8,676,009		$	-		$	(2,492	)	$	8,673,517
Natural gas		165,819			-			-			165,819
Competitive businesses		-			2,413,773			(24,036	)		2,389,737
Total		8,841,828			2,413,773			(26,528	)		11,229,073
OPERATING EXPENSES:
Operating and maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		2,183,559			309,917			(762	)		2,492,714
Purchased power		1,548,276			58,971			(42,280	)		1,564,967
Nuclear refueling outage expenses		105,000			150,617			-			255,618
Other operation and maintenance		1,950,567			905,453			11,739			2,867,758
Decommissioning		109,144			81,450			-			190,595
Taxes other than income taxes		431,619			102,961			1,446			536,026
Depreciation and amortization		918,453			179,188			4,561			1,102,202
Other regulatory charges (credits) - net		205,959			-			-			205,959
Total		7,452,577			1,788,557			(25,296	)		9,215,839
Gain on sale of investment		-			-			-			-
OPERATING INCOME		1,389,251			625,216			(1,232	)		2,013,234
OTHER INCOME (DEDUCTIONS):
Allowance for equity funds used during construction		84,305			-			-			84,305
Interest and investment income		158,737			136,492			(166,095	)		129,134
Other than temporary impairment losses		-			(140	)		-			(140	)
Miscellaneous – net		(25,377	)		(23,637	)		(10,257	)		(59,271	)
Total		217,665			112,715			(176,352	)		154,028
INTEREST EXPENSE:
Interest expense		493,632			20,634			37,255			551,521
Allowance for borrowed funds used during construction		(37,893	)		-			-			(37,894	)
Total		455,739			20,634			37,255			513,627
INCOME BEFORE INCOME TAXES		1,151,177			717,297			(214,839	)		1,653,635
Income taxes		27,311			225,456			33,496			286,263
CONSOLIDATED NET INCOME		1,123,866			491,841			(248,335	)		1,367,372
Preferred dividend requirements of subsidiaries		17,329			3,245			359			20,933
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION	$	1,106,537		$	488,596		$	(248,694	)	$	1,346,439
Earnings Per Average Common Share:
Basic		$6.24			$2.75			$(1.40)			$7.59
Diluted		$6.20			$2.74			$(1.39)			$7.55

Totals may not foot due to rounding.

15

FINANCIAL RESULTS

CONSOLIDATED BALANCE SHEETS (unaudited)

In thousands, as of December 31,	2011			2010			2009			2008			2007
ASSETS
CURRENT ASSETS:
Cash and cash equivalents:
Cash	$	81,468		$	76,290		$	85,861		$	115,876		$	126,652
Temporary cash investments		612,970			1,218,182			1,623,690			1,804,615			1,127,076
Total cash and cash equivalents		694,438			1,294,472			1,709,551			1,920,491			1,253,728
Securitization recovery trust account		50,304			43,044			13,098			12,062			19,273
Accounts receivable:
Customer		568,558			602,796			553,692			734,204			610,724
Allowance for doubtful accounts		(31,159	)		(31,777	)		(27,631	)		(25,610	)		(25,789	)
Other		166,186			161,662			152,303			206,627			303,060
Accrued unbilled revenues		298,283			302,901			302,463			282,914			288,076
Total accounts receivable		1,001,868			1,035,582			980,827			1,198,135			1,176,071
Deferred fuel costs		209,776			64,659			126,798			167,092			-
Accumulated deferred income taxes		9,856			8,472			-			7,307			38,117
Fuel inventory – at average cost		202,132			207,520			196,855			216,145			208,584
Materials and supplies – at average cost		894,756			866,908			825,702			776,170			692,376
Deferred nuclear refueling outage costs		231,031			218,423			225,290			221,803			172,936
System agreement cost equalization		36,800			52,160			70,000			394,000			268,000
Prepaid taxes		-			301,807			184,819			-			46,924
Prepayments and other		291,742			246,036			201,221			247,184			82,238
Total		3,622,703			4,339,083			4,534,161			5,160,389			3,958,247
OTHER PROPERTY AND INVESTMENTS:
Investment in affiliates – at equity		44,876			40,697			39,580			66,247			78,992
Decommissioning trust funds		3,788,031			3,595,716			3,211,183			2,832,243			3,307,636
Non-utility property – at cost (less accumulated depreciation)		260,436			257,847			247,664			231,115			220,204
Other		416,423			405,946			120,273			107,939			82,563
Total		4,509,766			4,300,206			3,618,700			3,237,544			3,689,395
PROPERTY, PLANT AND EQUIPMENT:
Electric		39,385,524			37,153,061			36,343,772			34,495,406			32,959,022
Property under capital lease		809,449			800,078			783,096			745,504			740,095
Natural gas		343,550			330,608			314,256			303,769			300,767
Construction work in progress		1,779,723			1,661,560			1,547,319			1,712,761			1,054,833
Nuclear fuel under capital lease		-			-			527,521			465,374			361,502
Nuclear fuel		1,546,167			1,377,962			739,827			636,813			665,620
Total property, plant and equipment		43,864,413			41,323,269			40,255,791			38,359,627			36,081,839
Less – accumulated depreciation and amortization		18,255,128			17,474,914			16,866,389			15,930,513			15,107,569
Property, plant and equipment – net		25,609,285			23,848,355			23,389,402			22,429,114			20,974,270
DEFERRED DEBITS AND OTHER ASSETS:
Regulatory assets:
Regulatory asset for income taxes - net		799,006			845,725			816,856			581,719			595,743
Other regulatory assets (includes securitization property of $1,009,103 as of December 31, 2011, $882,346 as of December 31, 2010, $818,047 as of December 31, 2009 $296,083 as of December 31, 2008, and $313,404 as of December 31, 2007)		4,636,871			3,838,237			3,647,154			3,615,104			2,971,399
Deferred fuel costs		172,202			172,202			172,202			168,122			168,122
Goodwill		377,172			377,172			377,172			377,172			377,172
Accumulated deferred income taxes		19,003			54,523			-			-			-
Other		955,691			909,773			1,006,306			1,047,654			908,654
Total		6,959,945			6,197,632			6,019,690			5,789,771			5,021,090
TOTAL ASSETS	$	40,701,699		$	38,685,276		$	37,561,953		$	36,616,818		$	33,643,002

Certain prior year data has been reclassified to conform with current year presentation.

16

FINANCIAL RESULTS

CONSOLIDATED BALANCE SHEETS (unaudited)

In thousands, as of December 31,		2011			2010			2009			2008			2007
LIABILITIES AND EQUITY
CURRENT LIABILITIES:
Currently maturing long-term debt	$	2,192,733		$	299,548		$	711,957		$	544,460		$	996,757
Notes payable and commercial paper		108,331			154,135			30,031			55,034			25,037
Accounts payable		1,069,096			1,181,099			998,228			1,475,745			1,031,300
Customer deposits		351,741			335,058			323,342			302,303			291,171
Taxes accrued		278,235			-			-			75,210			-
Accumulated deferred income taxes		99,929			49,307			48,584			-			-
Interest accrued		183,512			217,685			192,283			187,310			187,968
Deferred fuel costs		255,839			166,409			219,639			183,539			54,947
Obligations under capital leases		3,631			3,388			212,496			162,393			152,615
Pension and other postretirement liabilities		44,031			39,862			55,031			46,288			34,795
System agreement cost equalization		80,090			52,160			187,204			460,315			268,000
Other		283,531			277,598			215,202			273,297			214,164
Total		4,950,699			2,776,249			3,193,997			3,765,894			3,256,754
NON-CURRENT LIABILITIES:
Accumulated deferred income taxes and taxes accrued		8,096,452			8,573,646			7,662,798			6,565,770			6,379,679
Accumulated deferred investment tax credits		284,747			292,330			308,395			325,570			343,539
Obligations under capital leases		38,421			42,078			354,233			343,093			220,438
Other regulatory liabilities		728,193			539,026			378,862			280,643			490,323
Decommissioning and asset retirement cost liabilities		3,296,570			3,148,479			2,939,539			2,677,495			2,489,061
Accumulated provisions		385,512			395,250			141,315			147,452			133,406
Pension and other postretirement liabilities		3,133,657			2,175,364			2,241,039			2,177,993			1,361,326
Long-term debt (includes securitization bonds of $1,070,556 as of December 31, 2011, $931,131 as of December 31, 2010, $838,349 as of December 31, 2009 $310,373 as of December 31, 2008, and $329,421 as of December 31, 2007)		10,043,713			11,317,157			10,705,738			11,174,289			9,728,135
Other		501,954			618,559			711,334			880,998			1,066,508
Total		26,509,219			27,101,889			25,443,253			24,573,303			22,212,415
Commitments and Contingencies
Subsidiaries preferred stock without sinking fund		186,511			216,738			217,343			217,029			217,162
EQUITY:
Common shareholders’ equity:
Common stock, $.01 par value, authorized 500,000,000 shares; issued 254,752,788 shares in 2011, 2010, and 2009, 248,174,087 shares in 2008 and 2007		2,548			2,548			2,548			2,482			2,482
Paid-in capital		5,360,682			5,367,474			5,370,042			4,869,303			4,850,769
Retained earnings		9,446,960			8,689,401			8,043,122			7,382,719			6,735,965
Accumulated other comprehensive income (loss)		(168,452	)		(38,212	)		(75,185	)		(112,698	)		8,320
Less – treasury stock, at cost (78,396,988 shares in 2011;
76,006,920 shares in 2010; 65,634,580 shares in 2009;
58,815,518 shares in 2008; 55,053,847 shares in 2007;)		5,680,468			5,524,811			4,727,167			4,175,214			3,734,865
Total common shareholders’ equity		8,961,270			8,496,400			8,613,360			7,966,592			7,862,671
Subsidiaries preferred stock without sinking fund		94,000			94,000			94,000			94,000			94,000
Total		9,055,270			8,590,400			8,707,360			8,060,592			7,956,671
TOTAL LIABILITIES AND EQUITY	$	40,701,699		$	38,685,276		$	37,561,953		$	36,616,818		$	33,643,002

Certain prior year data has been reclassified to conform with current year presentation.

17

FINANCIAL RESULTS

2011 CONSOLIDATING BALANCE SHEET (unaudited)

In thousands, as of December 31, 2011.	UTILITY			ENTERGY WHOLESALE COMMODITIES			PARENT & OTHER			CONSOLIDATED
ASSETS
CURRENT ASSETS:
Cash and cash equivalents:
Cash	$	77,711		$	3,754		$	3		$	81,468
Temporary cash investments		281,921			318,633			12,416			612,970
Total cash and cash equivalents		359,632			322,387			12,419			694,438
Securitization recovery trust account		50,304			-			-			50,304
Notes receivable		-			1,083,918			(1,083,918	)		-
Accounts receivable:
Customer		403,321			165,237			-			568,558
Allowance for doubtful accounts		(30,827	)		(332	)		-			(31,159	)
Associated companies		42,847			99,162			(142,009	)		-
Other		151,956			13,376			854			166,186
Accrued unbilled revenues		297,265			1,018			-			298,283
Total accounts receivable		864,562			278,461			(141,155	)		1,001,868
Deferred fuel costs		209,776			-			-			209,776
Accumulated deferred income taxes		141,804			4,655			(136,603	)		9,856
Fuel inventory – at average cost		196,246			5,886			-			202,132
Materials and supplies – at average cost		559,230			335,526			-			894,756
Deferred nuclear refueling outage costs		103,788			127,243			-			231,031
System agreement cost equalization		36,800			-			-			36,800
Prepaid taxes		-			79,165			(79,165	)		-
Prepayments and other		67,285			222,049			2,408			291,742
Total		2,589,427			2,459,290			(1,426,014	)		3,622,703
OTHER PROPERTY AND INVESTMENTS:
Investment in affiliates – at equity		1,147,271			44,764			(1,147,159	)		44,876
Decommissioning trust funds		1,639,951			2,148,080			-			3,788,031
Non-utility property – at cost (less accumulated depreciation)		174,029			71,888			14,519			260,436
Other		374,379			12,044			30,000			416,423
Total		3,335,630			2,276,776			(1,102,640	)		4,509,766
PROPERTY, PLANT AND EQUIPMENT:
Electric		34,487,985			4,894,128			3,411			39,385,524
Property under capital lease		809,449			-			-			809,449
Natural gas		343,111			439			-			343,550
Construction work in progress		1,420,163			358,902			658			1,779,723
Nuclear fuel		801,972			744,195			-			1,546,167
Total property, plant and equipment		37,862,680			5,997,664			4,069			43,864,413
Less – accumulated depreciation and amortization		17,238,272			1,016,507			349			18,255,128
Property, plant and equipment – net		20,624,408			4,981,157			3,720			25,609,285
DEFERRED DEBITS AND OTHER ASSETS:
Regulatory assets:
Regulatory asset for income taxes - net		799,006			-			-			799,006
Other regulatory assets (includes securitization property of
$1,009,103 as of December 31, 2011)		4,636,871			-			-			4,636,871
Deferred fuel costs		172,202			-			-			172,202
Goodwill		374,099			3,073			-			377,172
Accumulated deferred income taxes		4,313			9,232			5,458			19,003
Other		198,593			803,552			(46,454	)		955,691
Total		6,185,084			815,857			(40,996	)		6,959,945
TOTAL ASSETS	$	32,734,549			$10,533,080			$(2,565,930)			$40,701,699

Totals may not foot due to rounding.

18

FINANCIAL RESULTS

2011 CONSOLIDATING BALANCE SHEET (unaudited)

In thousands, as of December 31, 2011.		UTILITY			ENTERGY WHOLESALE COMMODITIES		PARENT & OTHER			CONSOLIDATED
LIABILITIES AND EQUITY
CURRENT LIABILITIES:
Currently maturing long-term debt	$	245,472		$	27,261	$	1,920,000		$	2,192,733
Notes payable and commercial paper:
Associated companies		-			138,862		(138,862	)		-
Other		108,331			-		-			108,331
Accounts payable:
Associated companies		14,839			36,878		(51,717	)		-
Other		787,516			280,663		917			1,069,096
Customer deposits		351,741			-		-			351,741
Taxes accrued		569,641			-		(291,406	)		278,235
Accumulated deferred income taxes		54,592			42,613		2,724			99,929
Interest accrued		169,710			490		13,312			183,512
Deferred fuel costs		255,839			-		-			255,839
Obligations under capital leases		3,631			-		-			3,631
Pension and other postretirement liabilities		37,858			6,173		-			44,031
System agreement cost equalization		80,090			-		-			80,090
Other		114,083			158,277		11,171			283,531
Total		2,793,343			691,217		1,466,139			4,950,699
NON-CURRENT LIABILITIES:
Accumulated deferred income taxes and taxes accrued		6,680,438			824,393		591,621			8,096,452
Accumulated deferred investment tax credits		284,747			-		-			284,747
Obligations under capital leases		38,421			-		-			38,421
Other regulatory liabilities		737,403			-		(9,210	)		728,193
Decommissioning and asset retirement cost liabilities		1,803,665			1,492,905		-			3,296,570
Accumulated provisions		379,331			1,849		4,332			385,512
Pension and other postretirement liabilities		2,463,493			670,164		-			3,133,657
Long-term debt (includes securitization bonds of $1,070,556 as of December 31, 2011)		8,936,342			107,744		999,627			10,043,713
Other		651,919			639,552		(789,517	)		501,954
Total		21,975,759			3,736,607		796,853			26,509,219
Commitments and Contingencies
Subsidiaries preferred stock without sinking fund		186,510			55,399		(55,398	)		186,511
EQUITY:
Common shareholders’ equity:
Common stock, $.01 par value, authorized 500,000,000 shares; issued 254,752,788 shares in 2011		2,161,268			327,937		(2,486,657	)		2,548
Paid-in capital		2,416,634			1,499,406		1,444,642			5,360,682
Retained earnings		3,417,829			4,118,292		1,910,839			9,446,960
Accumulated other comprehensive income (loss)		(190,794	)		104,222		(81,880	)		(168,452	)
Less – treasury stock, at cost (78,396,988 shares in 2011)		120,000			-		5,560,468			5,680,468
Total common shareholders’ equity		7,684,937			6,049,857		(4,773,524	)		8,961,270
Subsidiaries preferred stock without sinking fund		94,000			-		-			94,000
Total		7,778,937			6,049,857		(4,773,524	)		9,055,270
TOTAL LIABILITIES AND EQUITY	$	32,734,549			$10,533,080		$(2,565,930)			$40,701,699

Totals may not foot due to rounding.

19

FINANCIAL RESULTS

CONSOLIDATED STATEMENTS OF CASH FLOW (unaudited)

In thousands, for the years ended December 31,		2011			2010			2009			2008			2007
OPERATING ACTIVITIES:
Consolidated net income	$	1,367,372		$	1,270,305		$	1,251,050		$	1,240,535		$	1,159,954
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		1,745,455			1,705,331			1,458,861			1,391,689			1,264,727
Deferred income taxes, investment tax credits, and non-current taxes accrued		(280,029	)		718,987			864,684			333,948			476,241
Gain on sale of business		-			(44,173	)		-			-			-
Changes in working capital:
Receivables		28,091			(99,640	)		116,444			78,653			(62,646	)
Fuel inventory		5,393			(10,665	)		19,291			(7,561	)		(10,445	)
Accounts payable		(131,970	)		216,635			(14,251	)		(23,225	)		(103,048	)
Prepaid taxes and taxes accrued		580,042			(116,988	)		(260,029	)		122,134			(187,324	)
Interest accrued		(34,172	)		17,651			4,974			(652	)		11,785
Deferred fuel		(55,686	)		8,909			72,314			(38,500	)		912
Other working capital accounts		41,875			(160,326	)		(43,391	)		(119,296	)		(73,269	)
Changes in provisions for estimated losses		(11,086	)		265,284			(12,030	)		12,462			(59,292	)
Changes in other regulatory assets		(673,244	)		339,408			(415,157	)		(324,211	)		254,736
Changes in pensions and other postretirement liabilities		962,461			(80,844	)		71,789			828,160			(56,224	)
Other		(415,685	)		(103,793	)		(181,391	)		(169,808	)		(56,337	)
Net cash flow provided by operating activities		3,128,817			3,926,081			2,933,158			3,324,328			2,559,770
INVESTING ACTIVITIES:
Construction / capital expenditures		(2,040,027	)		(1,974,286	)		(1,931,245	)		(2,212,255	)		(1,578,030	)
Allowance for equity funds used during construction		86,252			59,381			59,545			44,523			42,742
Nuclear fuel purchases		(641,493	)		(407,711	)		(525,474	)		(423,951	)		(408,732	)
Proceeds from sale / leaseback of nuclear fuel		-			-			284,997			297,097			169,066
Proceeds from sale of assets and businesses		6,531			228,171			39,554			30,725			13,063
Payment for purchase of plant		(646,137	)		-			-			(266,823	)		(336,211	)
Insurance proceeds received for property damages		-			7,894			53,760			130,114			83,104
Changes in transition charge account		(7,260	)		(29,945	)		(1,036	)		7,211			(19,273	)
NYPA value sharing payment		(72,000	)		(72,000	)		(72,000	)		(72,000	)		-
Payments to storm reserve escrow account		(6,425	)		(296,614	)		(6,802	)		(248,863	)		-
Receipts from storm reserve escrow account		-			9,925			-			249,461			-
Decrease (increase) in other investments		(11,623	)		24,956			100,956			(73,431	)		41,720
Proceeds from nuclear decommissioning trust fund sales		1,360,346			2,606,383			2,570,523			1,652,277			1,583,584
Investment in nuclear decommissioning trust funds		(1,475,017	)		(2,730,377	)		(2,667,172	)		(1,704,181	)		(1,708,764	)
Net cash flow used in investing activities		(3,446,853	)		(2,574,223	)		(2,094,394	)		(2,590,096	)		(2,117,731	)
FINANCING ACTIVITIES:
Proceeds from the issuance of:
Long-term debt		2,990,881			3,870,694			2,003,469			3,456,695			2,866,136
Preferred equity		-			-			-			-			10,000
Common stock and treasury stock		46,185			51,163			28,198			34,775			78,830
Retirement of long-term debt		(2,437,372	)		(4,178,127	)		(1,843,169	)		(2,486,806	)		(1,369,945	)
Repurchase of common stock		(234,632	)		(878,576	)		(613,125	)		(512,351	)		(1,215,578	)
Redemption of subsidiary common and preferred stock		(30,308	)		-			(1,847	)		-			(57,827	)
Changes in credit borrowings – net		(6,501	)		(8,512	)		(25,000	)		30,000			-
Dividends paid:
Common stock		(589,605	)		(603,854	)		(576,956	)		(573,045	)		(507,327	)
Preferred equity		(20,933	)		(20,063	)		(19,958	)		(20,025	)		(25,875	)
Net cash flow provided by (used in) financing activities		(282,285	)		(1,767,275	)		(1,048,388	)		(70,757	)		(221,586	)
Effect of exchange rates on cash and cash equivalents		287			338			(1,316	)		3,288			30
Net increase (decrease) in cash and cash equivalents		(600,034	)		(415,079	)		(210,940	)		666,763			220,483
Cash and cash equivalents at beginning of period		1,294,472			1,709,551			1,920,491			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	$	694,438		$	1,294,472		$	1,709,551		$	1,920,491		$	1,253,728

Certain prior year data has been reclassified to conform with current year presentation.

20

FINANCIAL RESULTS

CONSOLIDATED STATEMENTS OF CASH FLOW (unaudited)

$ thousands, for the years ended December 31,	2011		2010	2009		2008	2007
SUPPLEMENTAL DISCLOSURE OF
CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest – net of amount capitalized	532,271		534,004	576,811		612,288	611,197
Income taxes	(2,042	)	32,144	43,057		137,234	376,808
Noncash financing activities:
Long-tern debt retired (equity unit notes)	-		-	(500,000	)	-	-
Common stock issued in settlement of equity unit purchase contracts	-		-	500,000		-	-

CASH FLOW INFORMATION BY BUSINESS

For the years ended December 31, 2011, 2010, 2009, 2008, and 2007.	UTILITY		ENTERGY WHOLESALE COMMODITIES		PARENT & OTHER		CONSOLIDATED
($ thousands)
2011
Net cash flow provided by operating activities	2,099,569		756,499		272,749		3,128,817
Net cash flow provided by (used in) investing activities	(2,346,218	)	(1,262,664	)	162,029		(3,446,853	)
Net cash flow provided by (used in) financing activities	(215,304	)	374,484		(441,465	)	(282,285	)
2010
Net cash flow provided by operating activities	2,941,596		629,787		354,698		3,926,081
Net cash flow provided by (used in) investing activities	(2,500,139	)	(399,439	)	325,355		(2,574,223	)
Net cash flow provided by (used in) financing activities	(859,141	)	(230,203	)	(677,930	)	(1,767,275	)
2009
Net cash flow provided by (used in) operating activities	1,586,020		2,626,034		(1,278,896	)	2,933,158
Net cash flow provided by (used in) investing activities	(1,465,824	)	(1,927,120	)	1,298,550		(2,094,394	)
Net cash flow provided by (used in) financing activities	553,107		(701,801	)	(899,694	)	(1,048,388	)
2008
Net cash flow provided by (used in) operating activities	2,379,258		1,258,581		(313,511	)	3,324,328
Net cash flow provided by (used in) investing activities	(2,845,157	)	(429,859	)	684,920		(2,590,096	)
Net cash flow provided by (used in) financing activities	250,309		(832,619	)	511,553		(70,757	)
2007
Net cash flow provided by (used in) operating activities	1,807,769		821,201		(69,200	)	2,559,770
Net cash flow provided by (used in) investing activities	(1,238,487	)	(846,926	)	(32,318	)	(2,117,731	)
Net cash flow provided by (used in) financing activities	(368,909	)	57,766		89,557		(221,586	)

Certain prior year data has been reclassified to conform with current year presentation.

21

FINANCIAL RESULTS

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY AND COMPREHENSIVE INCOME (unaudited)

				Common Shareholders’ Equity
	Subsidiaries’ Preferred Stock			Common Stock		Treasury Stock			Paid-in Capital			Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Total
	(In Thousands)
Balance at December 31, 2006		100,000			2,482		(2,644,390	)		4,827,265			6,113,042			(100,512	)		8,297,887
Consolidated net income (a)		25,105			-		-			-			1,134,849			-			1,159,954
Other comprehensive income		-			-		-			-			-			108,832			108,832
Common stock repurchases		-			-		(1,215,578	)		-			-			-			(1,215,578	)
Common stock issuances related to stock plans		-			-		125,103			23,504			-			-			148,607
Common stock dividends declared		-			-		-			-			(507,326	)		-			(507,326	)
Preferred stock issued		10,000			-		-			-			-			-			10,000
Preferred stock repurchased		(16,000	)		-		-			-			-			-			(16,000	)
Preferred dividend requirements of subsidiaries (a)		(25,105	)		-		-			-			-			-			(25,105	)
Adjustment related to FIN 48 implementation		-			-		-			-			(4,600	)		-			(4,600	)
Balance at December 31, 2007		94,000			2,482		(3,734,865	)		4,850,769			6,735,965			8,320			7,956,671
Consolidated net income (a)		19,969			-		-			-			1,220,566			-			1,240,535
Other comprehensive loss		-			-		-			-			-			(121,018	)		(121,018	)
Common stock repurchases		-			-		(512,351	)		-			-			-			(512,351	)
Common stock issuances related to stock plans		-			-		72,002			18,534			-			-			90,536
Common stock dividends declared		-			-		-			-			(573,924	)		-			(573,924	)
Preferred dividend requirements of subsidiaries (a)		(19,969	)		-		-			-			-			-			(19,969	)
Capital stock and other expenses		-			-		-			-			112			-			112
Balance at December 31, 2008		94,000			2,482		(4,175,214	)		4,869,303			7,382,719			(112,698	)		8,060,592
Consolidated net income (a)		19,958			-		-			-			1,231,092			-			1,251,050
Other comprehensive income		-			-		-			-			-			43,878			43,878
Common stock repurchases		-			-		(613,125	)		-			-			-			(613,125	)
Common stock issuances in settlement of equity unit purchase contracts		-			66		-			499,934			-			-			500,000
Common stock issuances related to stock plans		-			-		61,172			805			-			-			61,977
Common stock dividends declared		-			-		-			-			(576,913	)		-			(576,913	)
Preferred dividend requirements of subsidiaries (a)		(19,958	)		-		-			-			-			-			(19,958	)
Capital stock and other expenses		-			-		-			-			(141	)		-			(141	)
Adjustment for implementation of new accounting pronouncement		-			-		-			-			6,365			(6,365	)		-
Balance at December 31, 2009		94,000			2,548		(4,727,167	)		5,370,042			8,043,122			(75,185	)		8,707,360
Consolidated net income (a)		20,063			-		-			-			1,250,242			-			1,270,305
Other comprehensive income		-			-		-			-			-			36,973			36,973
Common stock repurchases		-			-		(878,576	)		-			-			-			(878,576	)
Common stock issuances related to stock plans		-			-		80,932			(2,568	)		-			-			78,364
Common stock dividends declared		-			-		-			-			(603,963	)		-			(603,963	)
Preferred dividend requirements of subsidiaries (a)		(20,063	)		-		-			-			-			-			(20,063	)
Balance at December 31, 2010		94,000			2,548		(5,524,811	)		5,367,474			8,689,401			(38,212	)		8,590,400
Consolidated net income (a)		20,933			-		-			-			1,346,439			-			1,367,372
Other comprehensive loss		-			-		-			-			-			(130,240	)		(130,240	)
Common stock repurchases		-			-		(234,632	)		-			-			-			(234,632	)
Common stock issuances related to stock plans		-			-		78,975			(6,792	)		-			-			72,183
Common stock dividends declared		-			-		-			-			(588,880	)		-			(588,880	)
Preferred dividend requirements of subsidiaries (a)		(20,933	)		-		-			-			-			-			(20,933	)
Balance at December 31, 2011		94,000			2,548		(5,680,468	)		5,360,682			9,446,960			(168,452	)		9,055,270

Certain prior year data has been reclassified to conform with current year presentation.

(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2011, 2010, 2009, 2008, and 2007 include $13.3 million, $13.3 million, $13.3 million, $13.3 million, and $14.2 million, respectively, of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented as equity.

22

FINANCIAL RESULTS

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

$ thousands, for the years ended December 31,		2011			2010			2009			2008			2007
NET INCOME	$	1,367,372		$	1,270,305		$	1,251,050		$	1,240,535		$	1,159,954
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss) (net of tax expense (benefit) of $34,411, ($7,088), $333, $78,837, and $57,185 for 2011 to 2007, respectively)		71,239			(11,685	)		(2,887	)		133,370			93,038
Pension and other postretirement liabilities (net of tax benefit (expense) of $131,198, $14,387, $34,415, $68,076, and ($29,994) for 2011 to 2007, respectively)		(223,090	)		(8,527	)		(35,707	)		(125,087	)		(1,236	)
Net unrealized investment gains (net of tax expense (benefit) of $19,368, $51,130, $102,845, ($108,049), and $23,562 for 2011 to 2007, respectively)		21,254			57,523			82,929			(126,013	)		17,060
Foreign currency translation (net of tax expense (benefit) of $192, ($182), ($246), ($1,770), and ($16) for 2011 to 2007, respectively)		357			(338	)		(457	)		(3,288	)		(30	)
Other comprehensive income (loss)		(130,240	)		36,973			43,878			(121,018	)		108,832
COMPREHENSIVE INCOME		1,237,132			1,307,278			1,294,928			1,119,517			1,268,786
Preferred dividend requirements of subsidiaries		20,933			20,063			19,958			19,969			25,105
COMPREHENSIVE INCOME ATTRIBUTABLE TO ENTERGY CORPORATION	$	1,216,199		$	1,287,215		$	1,274,970		$	1,099,548		$	1,243,681

23

CONSOLIDATED CAPITAL EXPENDITURES

HISTORICAL CAPITAL EXPENDITURES

($ millions)	2011		2010		2009			2008		2007
Utility
Maintenance		925		798		805			855		789
Other		1,121		777		767			1,333		527
Entergy Wholesale Commodities		712		471		437			357		597
Parent & Other		-		-		(6	)		6		1
Total Historical Capital Expenditures		2,758		2,046		2,003			2,551		1,914

PLANNED CAPITAL EXPENDITURES

($ millions)	2012		2013		2014
Maintenance Capital:
Utility:
Generation		128		129		131
Transmission		282		273		255
Distribution		433		485		496
Other		91		89		103
Total		934		976		985
Entergy Wholesale Commodities		90		120		107
Total Maintenance Capital		1,024		1,096		1,092
Capital Commitments:
Utility:
Generation		1,428		583		358
Transmission		170		128		264
Distribution		17		11		11
Other		45		47		35
Total		1,660		769		668
Entergy Wholesale Commodities		259		241		291
Total Capital Commitments		1,919		1,010		959
Total Planned Capital Expenditures		2,943		2,106		2,051

ENTERGY CORPORATION SECURITIES DETAIL

ENTERGY CORPORATION LONG-TERM DEBT

							CURRENT OR FIRST CALL PRICE
					MATURITY DATE	FIRST  CALL DATE				AS OF DECEMBER 31,
CUSIP		RATE								2011			2010		2009
										($	millions	)
	$3.5B Bank Credit Facility		0.75	%	08/12					$	1,920		$	1,632	$	2,566
	Bank Term Loan				06/10						-			-		60
29364GAB9	6.58% Notes		6.58	%	05/10	Now		MW	(T+.50%)		-			-		75
29364GB@1	6.9% Notes		6.9	%	11/10	Now		MW	(T+.50%)		-			-		140
29364GA@2	7.06% Notes		7.06	%	03/11	Now		MW	(T+.50%)		-			86		86
29364GAE3	3.625% Notes		3.625	%	09/15	Now		MW	(T+.35%)		550			550		-
29364GAF0	5.125% Notes		5.125	%	09/20	Now		MW	(T+.40%)		450			450		-
Total										$	2,920		$	2,718	$	2,927

(a) In December 2005, Entergy Corporation sold 10 million equity units with a stated amount of $50 each. An equity unit consisted of (1) a note, initially due February 2011 and initially bearing interest at an annual rate of 5.75%, and (2) a purchase contract that obligated the holder of the equity unit to purchase for $50 between 0.5705 and 0.7074 shares of Entergy Corporation common stock on or before February 17, 2009. Entergy paid the holders quarterly contract adjustment payments of 1.875% per year on the stated amount of $50 per equity unit. Under the terms of the purchase contracts, Entergy attempted to remarket the notes in February 2009 but was unsuccessful, the note holders put the notes to Entergy, Entergy retired the notes, and Entergy issued 6,598,000 shares of common stock in the settlement of the purchase contracts.

(b) On February 16, 2012, Entergy Gulf States Louisiana, L.L.C. sold 500,000 units ($51 million) of Class A preferred, non-voting, membership interest units of Entergy Holdings Company LLC that carry a 10% annual distribution rate. Distributions are payable quarterly commencing on September 15, 2008 and have a liquidation price of $100 per unit. The preferred membership interests are callable at the option of Entergy Holdings Company LLC after ten years under the terms of the LLC agreement. This preferred membership interest is reflected in the Parent & Other disclosure segment in ‘Other Non-Current Liabilities’ on the balance sheet.

SECURITIES RATINGS (OUTLOOK)

	CORPORATE CREDIT
As of June 2012.		MOODY’S	S&P
Entergy Corporation		Baa3 (stable)	BBB (outlook negative)

24

UTILITY SELECTED DATA

UTILITY QUARTERLY FINANCIAL METRICS

	2011										2010										YTD %
	1Q		2Q		3Q		4Q		YTD		1Q		2Q		3Q		4Q		YTD		CHANGE
GAAP MEASURES
As-Reported Net Income ($ millions)		164.3		248.4		524.1		169.7		1,106.5		138.6		225.8		333.6		114.3		812.4		36.2
Return on Average Invested Capital –
As-Reported (%)(a)		7.0		7.0		8.0		8.3		8.3		6.5		7.1		7.2		6.9		6.9		20.3
Return on Average Common Equity –
As-Reported (%)(a)		11.7		11.9		14.2		14.8		14.8		10.4		11.4		11.8		11.4		11.4		29.8
Debt to Capital Ratio (%)		54.7		54.7		54.3		54.0		54.0		55.8		54.9		55.0		54.3		54.3		(0.6	)
NON-GAAP MEASURES
Operational Earnings ($ millions)		164.3		248.4		524.1		169.7		1,106.5		138.6		225.8		333.6		114.3		812.4		36.2
Return on Average Invested Capital
– Operational (%)(a)		7.0		7.0		8.0		8.3		8.3		6.5		7.1		7.2		6.9		6.9		20.3
Return on Average Common Equity –
Operational (%)(a)		11.7		11.9		14.2		14.8		14.8		10.4		11.4		11.8		11.4		11.4		29.8
Debt to Capital Ratio, excluding securitization debt (%)		52.1		52.2		51.3		50.9		50.9		53.4		52.5		52.3		51.6		51.6		(1.4	)
Net Debt to Net Capital Ratio, excluding securitization debt (%)		50.7		51.5		49.8		49.8		49.8		50.1		49.3		48.8		48.9		48.9		1.8

^(a)  Rolling twelve months. Totals may not foot due to rounding.

UTILITY ANNUAL FINANCIAL METRICS

	2011		2010		2009		2008		2007
GAAP MEASURES
As-Reported Net Income ($ millions)		1,106.5		812.4		691.6		587.8		682.7
Return on Average Invested Capital – As-Reported (%)		8.3		6.9		6.4		6.0		6.9
Return on Average Common Equity – As-Reported (%)		14.8		11.4		10.1		8.9		10.6
Debt to Capital Ratio (%)		54.0		54.3		55.6		53.0		51.5
NON-GAAP MEASURES
Operational Earnings ($ millions)		1,106.5		812.4		691.6		587.8		696.4
Return on Average Invested Capital – Operational (%)		8.3		6.9		6.4		6.0		7.0
Return on Average Common Equity – Operational (%)		14.8		11.4		10.1		8.9		10.8
Debt to Capital Ratio, excluding securitization debt (%)		50.9		51.6		53.2		52.0		50.3
Net Debt to Net Capital Ratio, excluding securitization debt (%)		49.8		48.9		49.2		50.0		47.2

UTILITY SECURITIES RATINGS (OUTLOOK)

	MORTGAGE BONDS		PREFERRED STOCK
As of June 2012.	MOODY’S	S&P	MOODY’S	S&P
Entergy Arkansas, Inc.	A3 (stable)	A– (outlook negative)	Ba1		BB+
Entergy Gulf States Louisiana, L.L.C.	A3 (stable)	BBB+ (outlook negative)	Ba1		BB+
Entergy Louisiana, LLC	A3 (stable)	A– (outlook negative)	Ba1		BB+
Entergy Mississippi, Inc.	Baa1 (stable)	A– (outlook negative)	Ba2		BB+
Entergy New Orleans, Inc.	Baa3 (stable)	BBB+ (outlook negative)	B1		BB+
Entergy Texas, Inc.	Baa2 (stable)	BBB+ (outlook negative)	–		–
System Energy Resources, Inc.	Baa2 (stable)	BBB+ (outlook negative)	–		–

UTILITY HISTORICAL CAPITAL EXPENDITURES^(a)

($ millions)	2011		2010		2009		2008		2007
Entergy Arkansas		383		291		264		584		305
Entergy Gulf States Louisiana		219		237		274		360		168
Entergy Louisiana		734		428		468		584		322
Entergy Mississippi		166		224		131		156		157
Entergy New Orleans		57		80		62		103		94
Entergy Texas		173		163		188		284		167
System Energy Resources		235		56		91		86		84
Other(b)		79		96		94		31		19
Total		2,046		1,575		1,572		2,188		1,316

(a) Historical capital expenditures include storm capital spending.

(b) Corresponds to Entergy Services, Inc., Entergy Operations, Inc., and System Fuels, Inc.

Certain prior year data has been reclassified to conform with current year presentation.

25

UTILITY SELECTED DATA

UTILITY PLANNED CAPITAL EXPENDITURES

	2012
($ millions)	Entergy Arkansas		Entergy Gulf States Louisiana		Entergy Louisiana		Entergy Mississippi		Entergy New Orleans		Entergy Texas		System Energy Resources		Other(a)		Utility
Maintenance Capital:
Generation		34		19		27		10		2		15		19		1		128
Transmission		73		56		61		37		7		42		-		6		282
Distribution		113		59		98		72		27		64		-		-		433
Other		10		16		9		5		9		5		2		34		91
Total Maintenance Capital		230		150		195		124		45		126		21		41		934
Capital Commitments:
Generation		325		48		460		223		6		69		297		-		1,428
Transmission		44		39		47		37		-		3		-		-		170
Distribution		9		-		7		-		1		-		-		-		17
Other		16		2		3		2		12		4		-		6		45
Total Other Capital Commitments		394		89		517		262		19		76		297		6		1,660
Total Planned Capital Expenditures		624		239		712		386		64		202		318		47		2,594

Totals may not foot due to rounding.

(a) Corresponds to Entergy Services, Inc.

	2013
($ millions)	Entergy Arkansas		Entergy Gulf States Louisiana		Entergy Louisiana		Entergy Mississippi		Entergy New Orleans		Entergy Texas		System Energy Resources		Other(a)		Utility
Maintenance Capital:
Generation		35		28		27		11		3		11		14		1		129
Transmission		72		47		54		33		4		58		-		4		273
Distribution		123		64		124		75		28		70		-		-		485
Other		11		15		9		5		10		5		2		35		89
Total Maintenance Capital		241		154		214		124		45		144		16		40		976
Capital Commitments:
Generation		60		29		410		7		12		46		18		-		583
Transmission		32		26		31		25		-		15		-		-		128
Distribution		8		-		3		-		-		-		-		-		11
Other		11		1		4		1		13		3		-		14		47
Total Other Capital Commitments		111		56		448		33		25		64		18		14		769
Total Planned Capital Expenditures		352		210		662		157		70		208		34		54		1,745

Totals may not foot due to rounding.

(a) Corresponds to Entergy Services, Inc.

	2014
($ millions)	Entergy Arkansas		Entergy Gulf States Louisiana		Entergy Louisiana		Entergy Mississippi		Entergy New Orleans		Entergy Texas		System Energy Resources		Other(a)		Utility
Maintenance Capital:
Generation		37		23		32		6		1		13		18		1		131
Transmission		67		43		64		41		4		34		-		2		255
Distribution		115		68		135		84		24		71		-		-		496
Other		11		18		11		6		10		5		2		40		103
Total Maintenance Capital		230		152		242		137		39		123		20		43		985
Capital Commitments:
Generation		75		22		190		7		17		22		24		-		358
Transmission		71		23		36		26		2		106		-		-		264
Distribution		8		-		3		-		-		-		-		-		11
Other		4		-		7		1		12		3		-		8		35
Total Other Capital Commitments		158		45		236		34		31		131		24		8		668
Total Planned Capital Expenditures		388		197		478		171		70		254		44		51		1,653

Totals may not foot due to rounding.

(a) Corresponds to Entergy Services, Inc.

UTILITY FINANCIAL RESULTS

2011 UTILITY CONSOLIDATING INCOME STATEMENT (unaudited)

In thousands, for the year ending December 31, 2011.	EAI			EGSL			ELL			EMI			ENOI			ETI			SERI			OTHER/ ELIMINATIONS			UTILITY
OPERATING REVENUES:
Electric	$	2,084,310		$	2,069,548		$	2,508,915		$	1,266,470		$	529,228		$	1,757,199		$	563,411		$	(2,103,072	)	$	8,676,009
Natural gas		-			64,861			-			-			100,957			-			-			1			165,819
Total		2,084,310			2,134,409			2,508,915			1,266,470			630,185			1,757,199			563,411			(2,103,071	)		8,841,828
OPERATING EXPENSES:
Operation and maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		186,036			437,301			596,808			363,025			173,668			352,022			76,353			(1,654	)		2,183,559
Purchased power		659,464			780,711			843,099			339,061			207,604			775,067			-			(2,056,730	)		1,548,276
Nuclear refueling outage expenses		42,557			18,227			27,903			-			-			-			16,314			(1	)		105,000
Other operation and maintenance		511,592			351,070			470,783			210,657			106,817			214,191			136,495			(51,038	)		1,950,567
Decommissioning		38,064			14,189			24,658			-			-			-			31,460			773			109,144
Taxes other than income taxes		82,847			75,858			69,769			69,759			42,032			69,329			21,425			600			431,619
Depreciation and amortization		218,902			143,387			206,986			93,119			35,026			79,263			142,543			(773	)		918,453
Other regulatory charges (credits) – net		(13,506	)		(17,045	)		182,800			9,460			1,910			52,307			(11,781	)		1,814			205,959
Total		1,725,956			1,803,698			2,422,806			1,085,081			567,057			1,542,179			412,809			(2,107,009	)		7,452,577
OPERATING INCOME		358,354			330,711			86,109			181,389			63,128			215,020			150,602			3,938			1,389,251
OTHER INCOME:
Allowance for equity funds used during construction		7,660			9,094			33,033			7,755			622			3,781			22,359			1			84,305
Interest and investment income		16,533			40,945			87,487			249			154			5,528			8,294			(453	)		158,737
Miscellaneous – net		(4,172	)		(8,799	)		(3,520	)		(3,904	)		(1,234	)		(3,047	)		(699	)		(2	)		(25,377	)
Total		20,021			41,240			117,000			4,100			(458	)		6,262			29,954			(454	)		217,665
INTEREST AND OTHER CHARGES:
Interest expense		83,545			84,356			116,803			52,273			11,114			93,554			48,117			3,870			493,632
Allowance for borrowed funds used during construction		(2,826	)		(3,745	)		(17,406	)		(4,314	)		(282	)		(2,609	)		(6,711	)		-			(37,893	)
Total		80,719			80,611			99,397			47,959			10,832			90,945			41,406			3,870			455,739
INCOME BEFORE INCOME TAXES		297,656			291,340			103,712			137,530			51,838			130,337			139,150			(386	)		1,151,177
Income taxes		132,765			89,737			(370,211	)		28,801			15,862			49,492			74,953			5,912			27,311
CONSOLIDATED NET INCOME		164,891			201,603			473,923			108,729			35,976			80,845			64,197			(6,298	)		1,123,866
Preferred dividend requirements and other		6,873			825			6,950			2,828			965			-			-			(1,112	)		17,329
EARNINGS APPLICABLE TO COMMON STOCK/EQUITY	$	158,018		$	200,778		$	466,973		$	105,901		$	35,011		$	80,845		$	64,197		$	(5,186	)	$	1,106,537

Totals may not foot due to rounding.

26

UTILITY FINANCIAL RESULTS

2011 UTILITY CONSOLIDATING BALANCE SHEET (unaudited)

																					OTHER/
In thousands, as of December 31, 2011.	EAI			EGSL			ELL			EMI			ENOI			ETI			SERI		ELIMINATIONS			UTILITY
ASSETS
CURRENT ASSETS:
Cash and cash equivalents:
Cash	$	4,712		$	217		$	878		$	7		$	486		$	150		$	30,961	$	40,300		$	77,711
Temporary cash investments		17,887			24,628			-			9			9,348			65,139			154,196		10,714			281,921
Total cash and cash equivalents		22,599			24,845			878			16			9,834			65,289			185,157		51,014			359,632
Securitization recovery trust account		3,890			-			5,200			-			-			41,215			-		(1	)		50,304
Accounts receivable:
Customer		90,940			61,648			102,379			51,026			29,038			68,290			-		-			403,321
Allowance for doubtful accounts		(26,155	)		(843	)		(1,147	)		(756	)		(465	)		(1,461	)		-		-			(30,827	)
Associated companies		58,030			171,431			60,661			51,329			12,167			129,561			172,943		(613,275	)		42,847
Other		66,838			22,082			10,945			13,924			2,603			9,573			7,294		18,697			151,956
Accrued unbilled revenues		70,715			51,155			78,430			38,368			17,023			41,573			-		1			297,265
Total account receivable		260,368			305,473			251,268			153,891			60,366			247,536			180,237		(594,577	)		864,562
Deferred fuel costs		209,776			-			-			-			-			-			-		-			209,776
Accumulated deferred income taxes		-			-			-			11,694			6,419			88,436			-		35,255			141,804
Fuel inventory - at average cost		48,889			23,249			23,919			42,499			3,806			53,884			-		-			196,246
Materials and supplies - at average cost		143,343			114,075			140,561			35,716			9,392			29,810			86,333		-			559,230
Deferred nuclear refueling outage costs		49,047			21,066			24,197			-			-			-			9,479		(1	)		103,788
System agreement cost equalization		36,800			-			-			-			-			-			-		-			36,800
Prepayments and other		8,562			5,180			13,171			4,666			2,679			15,203			1,111		16,713			67,285
Total		783,274			493,888			459,194			248,482			92,496			541,373			462,317		(491,597	)		2,589,427
OTHER PROPERTY AND INVESTMENTS:
Investment in affiliates - at equity		-			339,664			807,424			-			-			783			-		(600	)		1,147,271
Decommissioning trust funds		541,657			420,917			253,968			-			-			-			423,409		-			1,639,951
Non-utility property - at cost less accumulated depreciation)		1,677			164,712			760			4,725			1,016			930			-		209			174,029
Storm reserve escrow account		-			90,249			201,249			31,844			11,996			-			-		-			335,338
Other		3,182			12,701			-			-			-			17,969			-		5,189			39,041
Total		546,516			1,028,243			1,263,401			36,569			13,012			19,682			423,409		4,798			3,335,630
PROPERTY, PLANT AND EQUIPMENT
Electric		8,079,732			7,068,657			7,859,136			3,274,031			812,329			3,338,608			3,438,424		617,068			34,487,985
Property under capital lease		1,234			-			274,334			10,721			-			-			491,023		32,137			809,449
Natural gas		-			129,950			-			-			213,160			-			-		1			343,111
Construction work in progress		120,211			122,051			559,437			105,083			13,610			90,856			357,826		51,089			1,420,163
Nuclear fuel		272,593			206,031			165,380			-			-			-			157,967		1			801,972
Total property, plant and equipment		8,473,770			7,526,689			8,858,287			3,389,835			1,039,099			3,429,464			4,445,240		700,296			37,862,680
Less - accumulated depreciation and amortization		3,833,596			3,906,353			3,606,706			1,210,092			525,621			1,289,166			2,518,190		348,548			17,238,272
Property, plant and equipment – net		4,640,174			3,620,336			5,251,581			2,179,743			513,478			2,140,298			1,927,050		351,748			20,624,408
DEFERRED DEBITS AND OTHER ASSETS:
Regulatory assets:
Regulatory asset for income taxes - net		87,357			173,724			175,952			65,196			-			129,924			124,777		42,076			799,006
Other regulatory assets		1,126,911			333,898			814,472			393,387			178,815			1,178,067			287,796		323,525			4,636,871
Deferred fuel costs		-			100,124			67,998			-			4,080			-			-		-			172,202
Long-term receivables - associated companies		-			-			-			-			-			31,254			-		(31,254	)		-
Goodwill		-			-			-			-			-			-			-		374,099			374,099
Accumulated deferred income taxes		-			-			-			-			-			-			-		4,313			4,313
Other		27,980			13,506			31,269			20,017			4,154			18,408			20,016		63,243			198,593
Total		1,242,248			621,252			1,089,691			478,600			187,049			1,357,653			432,589		776,002			6,185,084
TOTAL ASSETS	$	7,212,212		$	5,763,719		$	8,063,867		$	2,943,394		$	806,035		$	4,059,006		$	3,245,365	$	640,951		$	32,734,549

Totals may not foot due to rounding.

27

UTILITY FINANCIAL RESULTS

2011 UTILITY CONSOLIDATING BALANCE SHEET (unaudited)

																		OTHER/
In thousands, as of December 31, 2011.	EAI		EGSL			ELL			EMI			ENOI		ETI		SERI		ELIMINATIONS			UTILITY
LIABILITIES AND EQUITY
CURRENT LIABILITIES:
Currently maturing long-term debt	$	-	$	60,000		$	75,309		$	-		$	-	$	-	$	110,163	$	-		$	245,472
Notes payable and commercial paper:
Other		33,914		-			44,392			-			-		-		-		30,025			108,331
Accounts payable:
Associated companies		228,163		73,305			218,001			46,311			27,042		60,583		8,032		(646,598	)		14,839
Other		138,054		101,009			130,295			41,489			28,098		69,160		63,331		216,080			787,516
Customer deposits		81,074		49,734			86,099			68,610			21,878		38,294		-		6,052			351,741
Taxes accrued		36,281		107,367			31,338			45,536			-		40,311		92,455		216,353			569,641
Accumulated deferred income taxes		124,267		5,107			4,690			-			-		-		3,428		(82,900	)		54,592
Interest accrued		29,881		26,084			36,535			21,550			2,840		33,095		17,776		1,949			169,710
Deferred fuel costs		-		97,178			66,535			15,841			11,621		64,664		-		-			255,839
Obligations under capital leases		-		-			-			-			-		-		-		3,631			3,631
Pension and other postretirement liabilities		-		7,911			9,161			-			-		1,029		-		19,757			37,858
System agreement cost equalization		-		-			36,800			-			-		43,290		-		-			80,090
Other		23,305		23,866			31,675			17,474			4,197		4,847		2,591		6,128			114,083
Total		694,939		551,561			770,830			256,811			95,676		355,273		297,776		(229,523	)		2,793,343
NON-CURRENT LIABILITIES:
Accumulated deferred income taxes and taxes accrued		1,708,760		1,368,563			1,098,690			672,129			144,405		934,990		652,418		100,483			6,680,438
Accumulated deferred investment tax credits		42,939		81,520			73,283			6,372			1,539		19,339		57,865		1,890			284,747
Obligations under capital leases		-		-			-			8,112			-		-		-		30,309			38,421
Regulatory liability for income taxes - net		-		-			-			-			33,258		-		-		(33,258	)		-
Other regulatory liabilities		133,960		75,721			295,542			-			5,726		11,710		214,745		(1	)		737,403
Decommissioning and asset retirement cost liabilities		640,228		359,792			345,834			5,697			2,893		3,870		445,352		(1	)		1,803,665
Accumulated provisions		5,640		99,033			213,060			38,289			15,843		5,024		-		2,442			379,331
Pension and other postretirement liabilities		539,016		332,672			459,685			144,088			74,017		137,735		139,719		636,561			2,463,493
Long-term debt		1,875,921		1,482,430			2,177,003			920,439			166,537		1,677,127		636,885		-			8,936,342
Long-term payables - associated companies		-		31,254			-			-			-		-		-		(31,254	)		-
Gas system rebuild insurance proceeds		-		-			-			-			55,707		-		-		(55,707	)		-
Other		10,335		47,397			65,011			5,370			9,489		14,583		42		499,692			651,919
Total		4,956,799		3,878,382			4,728,108			1,800,496			509,414		2,804,378		2,147,026		1,151,156			21,975,759
Commitments and Contingencies
Subsidiaries preferred stock without sinking fund		116,350		-			-			50,381			19,780		-		-		(1	)		186,510
EQUITY:
Common stock or members’ equity		470		1,393,386			2,504,436			199,326			33,744		49,452		789,350		(2,808,896	)		2,161,268
Paid-in capital/capital stock expense and other		588,444		-			-			(690	)		36,294		481,994		-		1,310,592			2,416,634
Retained earnings		855,210		-			-			637,070			111,127		367,909		11,213		1,435,300			3,417,829
Accumulated other comprehensive income (loss)		-		(69,610	)		(39,507	)		-			-		-		-		(81,677	)		(190,794	)
Less – treasury stock, at cost		-		-			-			-			-		-		-		120,000			120,000
Total		1,444,124		1,323,776			2,464,929			835,706			181,165		899,355		800,563		(264,681	)		7,684,937
Subsidiaries preferred stock without sinking fund		-		10,000			100,000			-			-		-		-		(16,000	)		94,000
Total		1,444,124		1,333,776			2,564,929			835,706			181,165		899,355		800,563		(280,681	)		7,778,937
TOTAL LIABILITIES AND EQUITY	$	7,212,212	$	5,763,719		$	8,063,867		$	2,943,394		$	806,035	$	4,059,006	$	3,245,365	$	640,951		$	32,734,549

Totals may not foot due to rounding.

28

UTILITY FINANCIAL RESULTS

UTILITY SELECTED ANNUAL FINANCIAL METRICS

	2011		2010		2009		2008		2007
ENTERGY ARKANSAS, INC.
As-Reported Earnings ($ millions)		158.0		165.7		60.0		40.3		132.2
Less Special Items ($ millions)		-		-		-		-		(5.9	)
Operational Earnings ($ millions)		158.0		165.7		60.0		40.3		138.1
GAAP MEASURES
Return on Average Common Equity – As-Reported (%)		11.1		11.8		4.3		2.9		9.4
Return on Average Invested Capital – As-Reported (%)		6.2		6.7		3.7		3.2		6.5
Cash Flow Interest Coverage (# times)		7.9		6.7		5.3		6.3		5.2
Debt to Capital Ratio (%)		55.0		55.9		54.0		53.5		49.0
Total Debt ($ millions)		1,911		1,928		1,793		1,745		1,442
Total Preferred ($ millions)		116		116		116		116		116
Total Equity ($ millions)		1,444		1,404		1,412		1,400		1,385
NON-GAAP MEASURES
Return on Average Common Equity – Operational (%)		11.1		11.8		4.3		2.9		9.8
Return on Average Invested Capital – Operational (%)		6.4		6.8		3.7		3.2		6.7
Total Debt, excluding securitization debt ($ millions)		1,797		1,804		1,793		1,745		1,442
Debt to Capital Ratio, excluding securitization debt (%)		53.5		54.3		54.0		53.5		49.0
Net Debt to Net Capital Ratio, excluding securitization debt (%)		53.2		52.8		52.8		52.9		49.0
									2007 PRO FORMA(a)
ENTERGY GULF STATES LOUISIANA, L.L.C.
As-Reported Earnings ($ millions)		200.8		173.5		152.5		131.1		119.5
Less Special Items ($ millions)		-		-		-		-		(3.6	)
Operational Earnings ($ millions)		200.8		173.5		152.5		131.1		123.1
GAAP MEASURES
Return on Average Common Equity – As-Reported (%)		14.5		12.1		11.3		10.2		9.6
Return on Average Invested Capital – As-Reported (%)		8.5		7.5		6.7		5.8		6.5
Cash Flow Interest Coverage (# times)		7.0		8.4		3.1		5.4		3.9	(b)
Debt to Capital Ratio (%)		53.6		52.0		55.8		62.7		65.7
Total Debt ($ millions)		1,542		1,584		1,783		2,188		2,460
Total Preferred ($ millions)		10		10		10		10		10
Total Equity ($ millions)		1,324		1,454		1,403		1,293		1,274
NON-GAAP MEASURES
Return on Average Common Equity – Operational (%)		14.5		12.1		11.3		10.2		9.9
Return on Average Invested Capital – Operational (%)		8.5		7.7		7.8		7.8		7.9
Total Debt, excluding assumption debt ($ millions)		1,542		1,584		1,615		1,418		1,381
Debt to Capital Ratio, excluding assumption debt (%)		53.6		52.0		53.3		52.1		51.8
Net Debt to Net Capital Ratio, excluding assumption debt (%)		53.2		49.4		51.0		51.2		49.8
(a)    Effective December 31, 2007, Entergy Gulf States, Inc. completed a jurisdictional separation into two vertically integrated utility companies: Entergy Texas and Entergy Gulf States Louisiana. The above pro forma metrics for 2007 reflect the results as if the separation had occurred on January 1, 2007. (b)    See page 66 for Pro Forma calculation.
ENTERGY LOUISIANA, LLC
As-Reported Earnings ($ millions)		467.0		224.5		225.9		150.6		136.4
Less Special Items ($ millions)		-		-		-		-		(2.2	)
Operational Earnings ($ millions)		467.0		224.5		225.9		150.6		138.6
GAAP MEASURES
Return on Average Members’ Equity – As-Reported (%)		20.7		11.7		13.2		9.8		9.8
Return on Average Invested Capital – As-Reported (%)		12.1		7.6		8.2		7.1		7.1
Cash Flow Interest Coverage (# times)		5.9		10.4		2.3		14.0		5.6
Debt to Capital Ratio (%)		47.2		46.1		49.9		46.1		43.4
Total Debt ($ millions)		2,297		1,830		1,902		1,462		1,192
Total Preferred ($ millions)		100		100		100		100		100
Total Equity ($ millions)		2,465		2,037		1,812		1,608		1,454
NON-GAAP MEASURES
Return on Average Members’ Equity – Operational (%)		20.7		11.7		13.2		9.8		10.0
Return on Average Invested Capital – Operational (%)		12.4		7.6		8.2		7.1		7.2
Total Debt, excluding securitization debt ($ millions)		2,090		1,830		1,902		1,462		1,192
Debt to Capital Ratio, excluding securitization debt (%)		44.9		46.1		49.9		46.1		43.4
Net Debt to Net Capital Ratio, excluding securitization debt (%)		44.9		44.4		47.8		43.6		43.4

29

UTILITY FINANCIAL RESULTS

UTILITY SELECTED ANNUAL FINANCIAL METRICS (CONTINUED)

	2011		2010		2009		2008		2007
ENTERGY MISSISSIPPI, INC.
As-Reported Earnings ($ millions)		105.9		82.5		76.5		58.4		70.1
Less Special Items ($ millions)		-		-		-		-		-
Operational Earnings ($ millions)		105.9		82.5		76.5		58.4		70.1
GAAP MEASURES
Return on Average Common Equity – As-Reported (%)		13.5		11.6		11.2		8.8		11.0
Return on Average Invested Capital – As-Reported (%)		8.0		7.3		7.3		6.3		7.0
Cash Flow Interest Coverage (# times)		3.1		3.3		5.4		2.7		4.8
Debt to Capital Ratio (%)		51.2		51.7		53.4		49.4		49.8
Total Debt ($ millions)		931		839		852		703		704
Total Preferred ($ millions)		50		50		50		50		50
Total Equity ($ millions)		836		733		694		669		659
NON-GAAP MEASURES
Return on Average Common Equity – Operational (%)		13.5		11.6		11.2		8.8		11.0
Return on Average Invested Capital – Operational (%)		8.0		7.3		7.3		6.3		7.0
Net Debt to Net Capital Ratio (%)		51.2		51.7		50.5		49.4		48.4
ENTERGY NEW ORLEANS, INC.
As-Reported Earnings ($ millions)		35.0		30.1		29.5		33.4		23.0
Less Special Items ($ millions)		-		-		-		-		-
Operational Earnings ($ millions)		35.0		30.1		29.5		33.4		23.0
GAAP MEASURES
Return on Average Common Equity – As-Reported (%)		19.0		15.3		14.3		17.4		14.1
Return on Average Invested Capital – As-Reported (%)		11.5		8.9		8.2		9.4		7.7
Cash Flow Interest Coverage (# times)		5.1		4.9		9.8		5.3		11.5
Debt to Capital Ratio (%)		45.3		44.6		54.8		54.5		60.9
Total Debt ($ millions)		167		167		272		273		304
Total Preferred ($ millions)		20		20		20		20		20
Total Equity ($ millions)		181		188		205		208		175
NON-GAAP MEASURES
Return on Average Common Equity – Operational (%)		19.0		15.3		14.3		17.4		14.1
Return on Average Invested Capital – Operational (%)		11.5		8.9		8.2		9.4		7.7
Net Debt to Net Capital Ratio (%)		43.8		35.1		26.5		37.3		52.1
									2007 PRO FORMA(a)
ENTERGY TEXAS, INC.
As-Reported Net Income ($ millions)		80.8		66.2		63.8		57.9		58.9
Less Special Items ($ millions)		-		-		-		-		-
Operational Net Income ($ millions)		80.8		66.2		63.8		57.9		58.9
GAAP MEASURES
Return on Average Common Equity – As-Reported (%)		9.4		7.9		7.3		6.1		5.9
Return on Average Invested Capital – As-Reported (%)		5.4		4.9		5.4		4.5		4.9
Cash Flow Interest Coverage (# times)		3.6		1.4		3.7		1.1		3.0
Debt to Capital Ratio (%)		65.1		66.8		66.3		59.9		58.5
Total Debt ($ millions)		1,677		1,659		1,658		1,345		1,413
Total Preferred ($ millions)		-		-		-		-		-
Total Equity ($ millions)		899		824		844		900		1,004
NON-GAAP MEASURES
Return on Average Common Equity – Operational (%)		9.4		7.9		7.3		6.6		7.0
Return on Average Invested Capital – Operational (%)		7.8		7.3		7.1		5.5		5.7
Total Debt, excluding securitization debt ($ millions)		927		852		820		1,035		1,083
Total Equity, excluding equity infusion from parent returned beginning of 08 ($ millions)		899		824		844		900		854
Debt to Capital Ratio, excluding securitization debt and equity infusion from parent (%)		50.8		50.8		49.3		53.5		55.9
Net Debt to Net Capital Ratio, excluding securitization debt and equity infusion from parent (%)		48.9		49.8		42.3		53.4		47.9

(a) Effective December 31, 2007, Entergy Gulf States, Inc. completed a jurisdictional separation into two vertically integrated utility companies: Entergy Texas   and Entergy Gulf States Louisiana. The above pro forma metrics for 2007 reflect the results as if the separation had occurred on January 1, 2007.

Certain prior year data has been reclassified to conform with current year presentation.

30

UTILITY FINANCIAL RESULTS

UTILITY SELECTED ANNUAL FINANCIAL METRICS (CONTINUED)

	2011		2010		2009		2008		2007
SYSTEM ENERGY RESOURCES, INC.
As-Reported Net Income ($ millions)		64.2		82.6		48.9		91.1		136.1
Less Special Items ($ millions)		-		-		-		-		(1.9	)
Operational Net Income ($ millions)		64.2		82.6		48.9		91.1		138.0
GAAP MEASURES
Return on Average Common Equity – As-Reported (%)		8.0		10.1		5.8		10.6		15.8
Return on Average Invested Capital – As-Reported (%)		5.6		6.8		4.4		7.1		9.8
Cash Flow Interest Coverage (# times)		11.4		5.9		10.7		4.9		4.9
Debt to Capital Ratio (%)		48.3		51.7		49.7		51.2		50.6
Total Debt ($ millions)		747		869		820		899		882
Total Preferred ($ millions)		-		-		-		-		-
Total Equity ($ millions)		801		812		830		856		862
NON-GAAP MEASURES
Return on Average Common Equity – Operational (%)		8.0		10.1		5.8		10.6		16.0
Return on Average Invested Capital – Operational (%)		5.6		6.8		4.4		7.1		9.9
Net Debt to Net Capital Ratio (%)		41.2		42.7		40.1		48.2		47.4

31

UTILITY SECURITIES DETAIL

UTILITY LONG-TERM DEBT AND PREFERRED STOCK

ENTERGY ARKANSAS, INC.

BONDS: CUSIP		TYPE*	RATE	MATURITY DATE	FIRST CALL DATE	CURRENT OR FIRST CALL PRICE	AS OF DECEMBER 31,
							2011			2010			2009
											(in millions	)
29364DAM2	4.50% Series	M	4.50%	06/10	Now	MW (T + .25%)	$	-		$	-		$	100
29364DAN0	5.40% Series	M	5.40%	08/13	Now	MW (T + .35%)		300			300			300
732835AW3	6.3% Series – Pope County(c)	G(b)	6.3%	2016	Now	100%		-			-			20
472712ER5	4.6% Series – Jefferson County(c)	G(b)	4.6%	2017	6/13/11	100%		55			55			55
29364DAE0	5.4% Series	M	5.4%	05/18	Now	100%		-			-			150
29364DAH3	5.0% Series	M	5.0%	07/18	Now	100%		115			115			115
732835BA0	6.3% Series – Pope County	G(b)	6.3%	2020	Now	100%		-			-			120
29364DAQ3	3.75% Series	M	3.75%	02/21	Now	MW (T + .20%)		350			350			-
453424BP	5.0% Series – Independence County(c)	G(b)	5.0%	2021	7/1/10	100%		45			45			45
29364DAL4	5.66% Series	M	5.66%	02/25	Now	MW (T + .20%)		175			175			175
29364D811	6.7% Series	M	6.7%	04/32	Now	100%		-			-			100
29364D795	6.0% Series	M	6.0%	11/32	Now	100%		-			-			100
29364DAJ9	5.9% Series	M	5.9%	06/33	Now	MW (T + .25%)		100			100			100
29364DAK6	6.38% Series	M	6.38%	11/34	Now	100%		60			60			60
29364D779	5.75% Series	M	5.75%	11/40	11/1/15	100%		225			225			-
Total bonds								1,425			1,425			1,439
OTHER LONG-TERM DEBT:
	5.60% Series G – Variable Interest Entity Note Payable		5.60%	09/11				-			35			-
	9% Series H – Variable Interest Entity Note Payable		9.00%	06/13				30			30			-
	5.69% Series I – Variable Interest Entity Note Payable		5.69%	07/14				70			70			-
	3.23% Series J – Variable Interest Entity Note Payable		3.23%	07/16				55			-			-
	2.30% Series Senior Secured – Securitization Bond		2.30%	08/21				114			124			-
	Long-Term United States Department of Energy Obligation(d)							181			181			181
	Unamortized Premium and Discount – Net							(1	)		(1	)		(1	)
	Other							2			-			-
TOTAL LONG-TERM DEBT(e)								1,876			1,864			1,619
Less Amount Due Within One Year								-			35			100
Long-Term Debt Excluding Amount Due Within One Year							$	1,876		$	1,829		$	1,519
Fair Value of Long-Term Debt(a)							$	1,756		$	1,713		$	1,463
*M = Mortgage Bond; G = Governmental Bond
Weighted-average annualized coupon rate								5.0	%		5.1	%		5.6	%

(a) The fair value excludes long-term DOE obligations of $181 million at Entergy Arkansas and includes debt due within one year. Fair values are based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker / dealer quotes, and issuer spreads.

(b) Consists of pollution control revenue bonds and environmental revenue bonds.

(c) The bonds are secured by a series of collateral first mortgage bonds.

(d) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner / licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt.

(e) Pursuant to the planned spin-off and merger of Entergy’s transmission business with ITC Holdings Corp., Entergy will issue approximately $1.775 billion of debt, with the proceeds being used for prepayment or redemption of outstanding preferred and debt securities at each Utility operating company. Although the aggregate amount and particular series of preferred and debt securities of each Utility operating company to be redeemed as well as the redemption dates are uncertain at this time and are expected to remain subject to change, each Utility operating company currently anticipates that debt securities in the following approximate aggregate amounts will be reedemed prior to or following the spin off and merger: $0.51 billion for Entergy Arkansas, $0.27 billion for Entergy Gulf States Louisiana, $0.38 billion for Entergy Louisiana, $0.29 billion for Entergy Mississippi, $0.01 billion for Entergy New Orleans, and $0.30 billion for Entergy Texas. See pgs. 12 - 14 of 2011 10-K for further detail.

Totals may not foot due to rounding.

PREFERRED STOCK:					SHARES AUTHORIZED AND OUTSTANDING AS OF DECEMBER 31,						AS OF DECEMBER 31,							CALL PRICE PER SHARE AS OF DECEMBER 31,
CUSIP		RATE			2011		2010		2009		2011		2010			2009		2011
	Without sinking fund:													(in millions	)
	Cumulative, $100 par value:
29364D209	4.32% Series		4.32	%		70,000		70,000		70,000	$	7	$	7		$	7		$103.65
29364D506	4.72% Series		4.72	%		93,500		93,500		93,500		9		9			9		107.00
29364D308	4.56% Series		4.56	%		75,000		75,000		75,000		8		8			8		102.83
29364D407	4.56% 1965 Series		4.56	%		75,000		75,000		75,000		8		8			8		102.50
29364D605	6.08% Series		6.08	%		100,000		100,000		100,000		10		10			10		102.83
	Cumulative, $25 par value:
29364D787	6.45% Series(a)		6.45	%		3,000,000		3,000,000		3,000,000		75		75			75		-
	Total without sinking fund (b)					3,413,500		3,413,500		3,413,500	$	116	$	116		$	116

(a) Series is callable at par.

(b) Pursuant to the planned spin-off and merger of Entergy’s transmission business with ITC Holdings Corp., Entergy will issue approximately $1.775 billion of debt, with the proceeds being used for prepayment or redemption of outstanding preferred and debt securities at each Utility operating company. Although the aggregate amount and particular series of preferred and debt securities of each Utility operating company to be redeemed as well as the redemption dates are uncertain at this time and are expected to remain subject to change, each Utility operating company currently anticipates that all of its outstanding preferred securities, if any, will be redeemed or otherwise retired prior to the spin off and merger. See pgs. 12 - 14 of 2011 10-K for further detail.

Totals may not foot due to rounding.

32

UTILITY LONG-TERM DEBT AND PREFERRED STOCK

ENTERGY GULF STATES LOUISIANA, L.L.C.

BONDS: CUSIP		TYPE*	RATE	MATURITY DATE	FIRST CALL DATE	CURRENT OR FIRST CALL PRICE	AS OF DECEMBER 31,
							2011			2010			2009
											(in millions	)
128318BL5	5.45% Series – Calcasieu Parish	G(b,c)	5.45%	2010	Now	100%		-			-			12
29364LAQ5	4.875% Series	M(b)	4.875%	11/11	Now	100%		-			-			200
29364LAF9	6.0% Series	M(b)	6.0%	12/12	Now	100%		-			-			-
128318BH4	6.75% Series – Calcasieu Parish	G(b,c)	6.75%	2012	Now	100%		-			26			26
730816AF9	6.7% Series – Pointe Coupee Parish	G(b,c)	6.7%	2013	Now	100%		-			9			9
29364LAS1	5.6% Series	M(b)	5.6%	12/14	Now	100%		-			-			-
450877AJ	5.7% Series – Iberville Parish	G(b,c)	5.7%	2014	Now	100%		-			12			12
29364LAU6	5.70% Series	M(b)	5.70%	06/15	Now	MW (T +. 30%)		-			-			200
29364LAN2	5.25% Series	M(b)	5.25%	08/15	Now	100%		-			-			92
952789AQ8	5.8% Series – West Feliciana Parish	G(b,c)	5.8%	2015	Now	100%		-			-			15
952789AW5	7.0% Series – West Feliciana Parish	G(b,c)	7.0%	2015	Now	100%		-			-			17
546398K23	2.875% Series – Louisiana Public Facilities Authority	G(c,d)	2.875%	2015	Non-Call Life			32			32			-
952789AR6	5.8% Series – West Feliciana Parish	G(b,c)	5.8%	2016	Now	100%		11			11			20
29365PAM4	6.00% Series	M	6.00%	05/18	Now	MW (T + .40%)		375			375			375
29365PAQ5	3.95% Series	M	3.95%	10/20	Now	MW (T +. 25%)		250			250			-
29365PAP7	5.59% Series	M	5.59%	10/24	Now	MW (T + .40%)		300			300			300
952789BB0	6.6% Series – West Feliciana Parish	G(b,c)	6.6%	2028	Now	100%		-			-			22
546398J90	5.0% Series – Louisiana Public Facilities Authority	G(c,d)	5.0%	2028	9/1/15	100%		84			84			-
29364LAL6	6.2% Series	M(b)	6.2%	07/33	Now	MW (T + .15%)		240			240			240
29364LAT9	6.18% Series	M(b)	6.18%	03/35	Now	MW (T + .30%)		85			85			85
	Total bonds							1,377			1,424			1,625
OTHER LONG-TERM DEBT:
	5.41% Series O – Variable Interest Entity Note Payable		5.41%	07/12				60			60			-
	5.56% Series N – Variable Interest Entity Note Payable		5.56%	05/13				75			75			-
	Credit Facility – weighted average rate 2.25%		2.25%	07/13				29			24			-
	Unamortized Premium and Discount – Net							(2	)		(2	)		(2	)
	Other							4			4			4
TOTAL LONG-TERM DEBT(e)								1,542			1,584			1,626
Less Amount Due Within One Year								60			-			12
Long-Term Debt Excluding Amount Due Within One Year							$	1,482		$	1,584		$	1,614
Fair Value of Long-Term Debt(a)							$	1,642		$	1,644		$	1,638
*M = Mortgage Bond; G = Governmental Bond
Weighted-average annualized coupon rate								5.4	%		5.5	%		5.8	%

(a) The fair value includes debt due within one year. Fair values are based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker / dealer quotes, and issuer spreads.

(b) Entergy Gulf States Louisiana was primarily liable for all of the long-term debt issued by Entergy Gulf States, Inc. that was outstanding on December 31, 2007. Under a debt assumption agreement with Entergy Gulf States Louisiana, Entergy Texas assumed approximately 46% of this long-term debt. Entergy Gulf States Louisiana recorded an assumption asset on its balance sheet to reflect the long-term debt assumed by Entergy Texas. By June 2010, Entergy Texas had repaid the outstanding assumed debt and the debt assumption agreement was terminated.

(c) Consists of pollution control revenue bonds and environmental revenue bonds.

(d) The bonds are secured by a series of collateral first mortgage bonds.

(e) Pursuant to the planned spin-off and merger of Entergy’s transmission business with ITC Holdings Corp., Entergy will issue approximately $1.775 billion of debt, with the proceeds being used for prepayment or redemption of outstanding preferred and debt securities at each Utility operating company. Although the aggregate amount and particular series of preferred and debt securities of each Utility operating company to be redeemed as well as the redemption dates are uncertain at this time and are expected to remain subject to change, each Utility operating company currently anticipates that debt securities in the following approximate aggregate amounts will be reedemed prior to or following the spin off and merger: $0.51 billion for Entergy Arkansas, $0.27 billion for Entergy Gulf States Louisiana, $0.38 billion for Entergy Louisiana, $0.29 billion for Entergy Mississippi, $0.01 billion for Entergy New Orleans, and $0.30 billion for Entergy Texas. See pgs. 12 - 14 of 2011 10-K for further detail.

Totals may not foot due to rounding.

PREFERRED MEMBERSHIP INTERESTS:					SHARES / UNITS AUTHORIZED AND OUTSTANDING AS OF DECEMBER 31,						AS OF DECEMBER 31,						CALL PRICE PER SHARE / UNIT AS OF DECEMBER 31,
CUSIP		RATE			2011		2010		2009		2011		2010		2009		2011
	Without sinking fund:													(in millions)
	Cumulative, $100 liquidation value:
29364L763	8.25% Series(a)		8.25	%		100,000		100,000		100,000	$	10	$	10	$	10		-
	Authorized 6,000,000 shares, $100 par value, cumulative
	Total without sinking fund (b)					100,000		100,000		100,000	$	10	$	10	$	10

(a) Series is callable at par on and after December 15, 2015.

(b) Pursuant to the planned spin-off and merger of Entergy’s transmission business with ITC Holdings Corp., Entergy will issue approximately $1.775 billion of debt, with the proceeds being used for prepayment or redemption of outstanding preferred and debt securities at each Utility operating company. Although the aggregate amount and particular series of preferred and debt securities of each Utility operating company to be redeemed as well as the redemption dates are uncertain at this time and are expected to remain subject to change, each Utility operating company currently anticipates that all of its outstanding preferred securities, if any, will be redeemed or otherwise retired prior to the spin off and merger. See pgs. 12 - 14 of 2011 10-K for further detail.

Totals may not foot due to rounding.

33

UTILITY LONG-TERM DEBT AND PREFERRED STOCK

ENTERGY LOUISIANA, LLC

BONDS: CUSIP		TYPE*	RATE	MATURITY DATE	FIRST CALL DATE	CURRENT OR FIRST CALL PRICE	AS OF DECEMBER 31,
							2011			2010			2009
											(in millions	)
29364WAD0	4.67% Series	M	4.67%	06/10	Now	MW (T + .20%)	$	-		$	-		$	55
29364WAG3	5.83% Series	M	5.83%	11/10	Now	100%		-			-			150
29364WAC2	5.09% Series	M	5.09%	11/14	Now	100%		-			-			115
29364WAE8	5.56% Series	M	5.56%	09/15	Now	MW (T + .25%)		-			-			100
29364WAJ7	6.50% Series	M	6.50%	09/18	Now	MW (T + .40%)		300			300			300
29364WAA6	5.5% Series	M	5.5%	04/19	Now	100%		-			-			100
29364WAN8	4.8% Series	M	4.8%	05/21	Now	MW (T + .25%)		200			-			-
29364WAK4	5.40% Series	M	5.40%	11/24	Now	MW (T + .35%)		400			400			400
29364WAM0	4.44% Series	M	4.44%	01/26	Now	MW (T + .30%)		250			250			-
546398J82	5.0% Series – Louisiana Public Facilities Authority	G(b,c)	5.0%	2030	12/1/15	100%		115			115			-
29364W207	7.6% Series	M	7.6%	04/32	Now	100%		-			-			150
29364WAB4	6.4% Series	M	6.4%	10/34	Now	100%		70			70			70
29364WAF5	6.3% Series	M	6.3%	09/35	Now	MW (T + .35%)		100			100			100
29364W306	6.0% Series	M	6.0%	03/40	3/15/15	100%		150			150			-
29364W405	5.875% Series	M	5.875%	06/41	11/23/15	100%		150			150			-
	Total bonds							1,735			1,535			1,540
OTHER LONG-TERM DEBT:
	Waterford 3 Lease Obligation 7.45%		7.45%					188			224			241
	Bank Credit Facility – weighted average rate 0.67%		0.67%					50			-			-
	5.69% Series E – Variable Interest Entity Note Payable		5.69%	07/14				50			50			-
	3.30% Series F – Variable Interest Entity Note Payable		3.30%	03/16				20			-			-
	2.04% Series Senior Secured - Securitization Bond		2.04%	06/21				207			-			-
	Unamortized Premium and Discount – Net							(2	)		(2	)		(2	)
	Other							4			-			-
TOTAL LONG-TERM DEBT(d)								2,252			1,807			1,780
Less Amount Due Within One Year								75			36			222
Long-Term Debt Excluding Amount Due Within One Year							$	2,177		$	1,772		$	1,557
Fair Value of Long-Term Debt(a)							$	2,211		$	1,515		$	1,566
*M = Mortgage Bond; G = Governmental Bond
Weighted-average annualized coupon rate								4.9	%		5.9	%		6.1	%

(a) The fair value excludes lease obligations of $188 million at Entergy Louisiana and includes debt due within one year. Fair values are based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker / dealer quotes, and issuer spreads.

(b) Consists of pollution control revenue bonds and environmental revenue bonds.

(c) The bonds are secured by a series of collateral first mortgage bonds.

(d) Pursuant to the planned spin-off and merger of Entergy’s transmission business with ITC Holdings Corp., Entergy will issue approximately $1.775 billion of debt, with the proceeds being used for prepayment or redemption of outstanding preferred and debt securities at each Utility operating company. Although the aggregate amount and particular series of preferred and debt securities of each Utility operating company to be redeemed as well as the redemption dates are uncertain at this time and are expected to remain subject to change, each Utility operating company currently anticipates that debt securities in the following approximate aggregate amounts will be reedemed prior to or following the spin off and merger: $0.51 billion for Entergy Arkansas, $0.27 billion for Entergy Gulf States Louisiana, $0.38 billion for Entergy Louisiana, $0.29 billion for Entergy Mississippi, $0.01 billion for Entergy New Orleans, and $0.30 billion for Entergy Texas. See pgs. 12 - 14 of 2011 10-K for further detail.

Totals may not foot due to rounding.

PREFERRED MEMBERSHIP INTERESTS:					UNITS AUTHORIZED AND OUTSTANDING AS OF DECEMBER 31,						AS OF DECEMBER 31,						CALL PRICE PER UNIT AS OF DECEMBER 31,
CUSIP		RATE			2011		2010		2009		2011		2010		2009		2011
	Without sinking fund:													(in millions)
	Cumulative, $100 liquidation value:
293649208	6.95% Series(a)		6.95	%		1,000,000		1,000,000		1,000,000	$	100	$	100	$	100		-
	Total without sinking fund  (b)					1,000,000		1,000,000		1,000,000	$	100	$	100	$	100

(a) Series is callable at par.

(b) Pursuant to the planned spin-off and merger of Entergy’s transmission business with ITC Holdings Corp., Entergy will issue approximately $1.775 billion of debt, with the proceeds being used for prepayment or redemption of outstanding preferred and debt securities at each Utility operating company. Although the aggregate amount and particular series of preferred and debt securities of each Utility operating company to be redeemed as well as the redemption dates are uncertain at this time and are expected to remain subject to change, each Utility operating company currently anticipates that all of its outstanding preferred securities, if any, will be redeemed or otherwise retired prior to the spin off and merger. See pgs. 12 - 14 of 2011 10-K for further detail.

34

UTILITY LONG-TERM DEBT AND PREFERRED STOCK

ENTERGY MISSISSIPPI, INC.

BONDS: CUSIP		TYPE*	RATE	MATURITY DATE	FIRST CALL DATE	CURRENT OR FIRST CALL PRICE	AS OF DECEMBER 31,
							2011			2010			2009
											(in millions	)
29364NAM0	4.65% Series	M	4.65%	05/11	Now	MW (T + .30%)	$	-		$	80		$	80
29364NAH1	5.15% Series	M	5.15%	02/13	Now	MW (T + .20%)		100			100			100
29364NAN8	5.92% Series	M	5.92%	02/16	Now	MW (T + .30%)		-			100			100
29364NAQ1	3.25% Series	M	3.25%	06/16	Now	MW (T + .25%)		125			-			-
29364NAK4	4.95% Series	M	4.95%	06/18	Now	100%		95			95			95
29364NAP3	6.64% Series	M	6.64%	07/19	Now	MW (T + .50%)		150			150			150
605277AF9	4.60% Series – Mississippi Business Finance Corp.	G(b,c)	4.60%	2022	10/1/09	100%		16			16			16
453424BN2	4.90% Series – Independence County(d)	G(b,c)	4.90%	2022	Now	100%		30			30			30
29364N876	6.0% Series	M	6.0%	11/32	Now	100%		75			75			75
29364N868	7.25% Series	M	7.25%	12/32	Now	100%		-			-			100
29364NAL2	6.25% Series	M	6.25%	04/34	Now	MW (T + .25%)		100			100			100
29364N843	6.20% Series	M	6.20%	04/40	4/15/15	100%		80			80			-
29364N835	6.00% Series	M	6.00%	05/51	5/1/16	100%		150			-			-
	Total bonds							921			826			846
OTHER LONG-TERM DEBT:
	Unamortized Premium and Discount – Net							(1	)		(1	)		(1	)
TOTAL LONG-TERM DEBT(e)								920			825			845
Less Amount Due Within One Year								-			80			-
Long-Term Debt Excluding Amount Due Within One Year							$	920		$	745		$	845
Fair Value of Long-Term Debt(a)							$	986		$	802		$	874
*M = Mortgage Bond; G = Governmental Bond
Weighted-average annualized coupon rate								5.5	%		5.7	%		5.9	%

(a) The fair value includes debt due within one year. Fair values are based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker / dealer quotes, and issuer spreads.

(b) Consists of pollution control revenue bonds and environmental revenue bonds.

(c) The bonds are secured by a series of collateral first mortgage bonds.

(d) In April 2008, Entergy Mississippi repurchased its $30 million of Auction Rate Independence County Pollution Control Revenue Bonds due July 2022. In June 2008, Entergy Mississippi remarketed the series and fixed the interest rate to maturity at 4.90%.

(e) Pursuant to the planned spin-off and merger of Entergy’s transmission business with ITC Holdings Corp., Entergy will issue approximately $1.775 billion of debt, with the proceeds being used for prepayment or redemption of outstanding preferred and debt securities at each Utility operating company. Although the aggregate amount and particular series of preferred and debt securities of each Utility operating company to be redeemed as well as the redemption dates are uncertain at this time and are expected to remain subject to change, each Utility operating company currently anticipates that debt securities in the following approximate aggregate amounts will be reedemed prior to or following the spin off and merger: $0.51 billion for Entergy Arkansas, $0.27 billion for Entergy Gulf States Louisiana, $0.38 billion for Entergy Louisiana, $0.29 billion for Entergy Mississippi, $0.01 billion for Entergy New Orleans, and $0.30 billion for Entergy Texas. See pgs. 12 - 14 of 2011 10-K for further detail.

Totals may not foot due to rounding.

PREFERRED STOCK:			SHARES AUTHORIZED AND OUTSTANDING AS OF DECEMBER 31,						AS OF DECEMBER 31,							CALL PRICE PER SHARE AS OF DECEMBER 31,
CUSIP		RATE	2011		2010		2009		2011		2010			2009		2011
												(in millions	)
	Without sinking fund:
	Cumulative, $100 par value:
29364N207	4.36% Series	4.36%		59,920		59,920		59,920	$	6	$	6		$	6		$  103.88
29364N306	4.56% Series	4.56%		43,887		43,887		43,887		4		4			4		107.00
29364N405	4.92% Series	4.92%		100,000		100,000		100,000		10		10			10		102.88
	Cumulative, $25 par value:
29364N850	6.25% Series(a)	6.25%		1,200,000		1,200,000		1,200,000		30		30			30		-
	Total without sinking fund (b)			1,403,807		1,403,807		1,403,807	$	50	$	50		$	50

(a) Series is callable at par.

(b) Pursuant to the planned spin-off and merger of Entergy’s transmission business with ITC Holdings Corp., Entergy will issue approximately $1.775 billion of debt, with the proceeds being used for prepayment or redemption of outstanding preferred and debt securities at each Utility operating company. Although the aggregate amount and particular series of preferred and debt securities of each Utility operating company to be redeemed as well as the redemption dates are uncertain at this time and are expected to remain subject to change, each Utility operating company currently anticipates that all of its outstanding preferred securities, if any, will be redeemed or otherwise retired prior to the spin off and merger. See pgs. 12 - 14 of 2011 10-K for further detail.

Totals may not foot due to rounding.

ENTERGY NEW ORLEANS, INC.

BONDS: CUSIP		TYPE*	RATE	MATURITY DATE	FIRST CALL DATE	CURRENT OR FIRST CALL PRICE	AS OF DECEMBER 31,
							2011			2010			2009
											(in millions	)
29364PAL7	4.98% Series	M	4.98%	07/10	Now	101%	$	-		$	-		$	30
29364PAF0	5.25% Series	M	5.25%	08/13	Now	MW (T + .25%)		70			70			70
29364PAD5	6.75% Series	M	6.75%	10/17	Now	100%		-			-			25
29364PAM5	5.10% Series	M	5.10%	12/20	Now	MW (T + .35%)		25			25			-
29364PAK9	5.6% Series	M	5.60%	09/24	9/1/08	100%		33			34			34
29364PAJ2	5.65% Series	M	5.65%	09/29	9/1/09	100%		38			39			39
	Total bonds							167			167			198
OTHER LONG-TERM DEBT:
	Affiliated Notes Payable(b)							-			-			74
	Unamortized Premium and Discount – Net							-			-			-
TOTAL LONG-TERM DEBT(c)								167			167			272
Less Amount Due Within One Year								-			-			104
Long-Term Debt Excluding Amount Due Within One Year							$	167		$	167		$	168
Fair Value of Long-Term Debt(a)							$	169		$	171		$	198
*M = Mortgage; G = Governmental
Weighted-average annualized coupon rate								5.4	%		5.4	%		5.5	%

(a) The fair value includes debt due within one year. Fair values are based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker / dealer quotes, and issuer spreads.

(b) The affiliate note payable at Entergy New Orleans that was due May 2010 was classified as current notes payable - associated companies in 2009.

(c) Pursuant to the planned spin-off and merger of Entergy’s transmission business with ITC Holdings Corp., Entergy will issue approximately $1.775 billion of debt, with the proceeds being used for prepayment or redemption of outstanding preferred and debt securities at each Utility operating company. Although the aggregate amount and particular series of preferred and debt securities of each Utility operating company to be redeemed as well as the redemption dates are uncertain at this time and are expected to remain subject to change, each Utility operating company currently anticipates that debt securities in the following approximate aggregate amounts will be reedemed prior to or following the spin off and merger: $0.51 billion for Entergy Arkansas, $0.27 billion for Entergy Gulf States Louisiana, $0.38 billion for Entergy Louisiana, $0.29 billion for Entergy Mississippi, $0.01 billion for Entergy New Orleans, and $0.30 billion for Entergy Texas. See pgs. 12 - 14 of 2011 10-K for further detail.

Totals may not foot due to rounding.

PREFERRED STOCK:					SHARES AUTHORIZED AND OUTSTANDING AS OF DECEMBER 31,						AS OF DECEMBER 31,							CALL PRICE PER SHARE AS OF DECEMBER 31,
CUSIP		RATE			2011		2010		2009		2011		2010			2009		2011
	Without sinking fund:													(in millions	)
	Cumulative, $100 par value:
29364P301	4.75% Series		4.75	%		77,798		77,798		77,798	$	8	$	8		$	8		$  105.00
29364P202	4.36% Series		4.36	%		60,000		60,000		60,000		6		6			6		104.58
29364P400	5.56% Series		5.56	%		60,000		60,000		60,000		6		6			6		102.59
	Total without sinking fund (a)					197,798		197,798		197,798	$	20	$	20		$	20

(a) Pursuant to the planned spin-off and merger of Entergy’s transmission business with ITC Holdings Corp., Entergy will issue approximately $1.775 billion of debt, with the proceeds being used for prepayment or redemption of outstanding preferred and debt securities at each Utility operating company. Although the aggregate amount and particular series of preferred and debt securities of each Utility operating company to be redeemed as well as the redemption dates are uncertain at this time and are expected to remain subject to change, each Utility operating company currently anticipates that all of its outstanding preferred securities, if any, will be redeemed or otherwise retired prior to the spin off and merger. See pgs. 12 - 14 of 2011 10-K for further detail.

Totals may not foot due to rounding.

35

UTILITY LONG-TERM DEBT AND PREFERRED STOCK

ENTERGY TEXAS, INC.

BONDS: CUSIP				MATURITY DATE	FIRST CALL DATE	CURRENT OR FIRST CALL PRICE	AS OF DECEMBER 31,
		TYPE*	RATE				2011			2010			2009
											(in millions	)
29364LAQ5	4.875% Series	M(c)	4.875%	11/11	Now	100%		-			-			28
29364LAU6	5.70% Series	M(c)	5.70%	06/15	Now	MW (T +. 30%)		-			-			92
29365TAB0	3.60% Series	M	3.60%	06/15	Now	MW (T +. 25%)		200			200			-
952789AR6	5.8% Series – West Feliciana Parish	G(b,c)	5.8%	2016	Now	100%		-			-			9
29365TAA2	7.125% Series	M	7.125%	02/19	Now	MW (T + .50%)		500			500			500
29365TAC8	4.1% Series	M	4.100%	09/21	Now	MW (T + .30%)		75			-			-
2936LAT9	6.18% Series	M(c)	6.18%	03/35	Now	MW (T + .30%)		-			-			39
29365T203	7.875% Series	M	7.875%	06/39	06/14	100%		150			150			150
	Total bonds							925			850			818
OTHER LONG-TERM DEBT:
29365QAA8	5.51% Series Senior Secured, Series A - Securitization Bond	5.51%	10/13					18			38			57
29365QAB6	5.79% Series Senior Secured, Series A - Securitization Bond	5.79%	10/18					122			122			122
29365QAC4	5.93% Series Senior Secured, Series A - Securitization Bond	5.93%	6/22					114			114			114
29365KAA1	2.12% Series Senior Secured - Securitization Bond		2.12%	02/16				132			170			183
29365KAB9	3.65% Series Senior Secured - Securitization Bond		3.65%	08/19				145			145			145
29365KAC7	4.38% Series Senior Secured - Securitization Bond		4.38%	11/23				219			219			219
	Unamortized Premium and Discount – Net							(3	)		(3	)		(4	)
	Other							5			5			5
TOTAL LONG-TERM DEBT(d)								1,677			1,659			1,658
Less Amount Due Within One Year								-			-			168
Long-Term Debt Excluding Amount Due Within One Year							$	1,677		$	1,659		$	1,490
Fair Value of Long-Term Debt(a)							$	1,906		$	1,822		$	1,747
*M = Mortgage Bond; G = Governmental Bond
Weighted-average annualized coupon rate								5.4	%		5.4	%		5.6	%

(a) The fair value includes debt due within one year. Fair values are based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker / dealer quotes, and issuer spreads.

(b) Consists of pollution control revenue bonds and environmental revenue bonds.

(c) Entergy Gulf States Louisiana was primarily liable for all of the long-term debt issued by Entergy Gulf States, Inc. that was outstanding on December 31, 2007. Under a debt assumption agreement with Entergy Gulf States Louisiana, Entergy Texas assumed approximately 46% of this long-term debt. Entergy Gulf States Louisiana recorded an assumption asset on its balance sheet to reflect the long-term debt assumed by Entergy Texas. By June 2010, Entergy Texas had repaid the outstanding assumed debt and the debt assumption agreement was terminated.

(d) Pursuant to the planned spin-off and merger of Entergy’s transmission business with ITC Holdings Corp., Entergy will issue approximately $1.775 billion of debt, with the proceeds being used for prepayment or redemption of outstanding preferred and debt securities at each Utility operating company. Although the aggregate amount and particular series of preferred and debt securities of each Utility operating company to be redeemed as well as the redemption dates are uncertain at this time and are expected to remain subject to change, each Utility operating company currently anticipates that debt securities in the following approximate aggregate amounts will be reedemed prior to or following the spin off and merger: $0.51 billion for Entergy Arkansas, $0.27 billion for Entergy Gulf States Louisiana, $0.38 billion for Entergy Louisiana, $0.29 billion for Entergy Mississippi, $0.01 billion for Entergy New Orleans, and $0.30 billion for Entergy Texas. See pgs. 12 - 14 of 2011 10-K for further detail.

Totals may not foot due to rounding.

SYSTEM ENERGY RESOURCES, INC.

BONDS:				MATURITY	FIRST CALL	CURRENT OR	AS OF DECEMBER 31,
CUSIP		TYPE*	RATE	DATE	DATE	FIRST CALL PRICE	2011			2010			2009
											(in millions	)
871911AR4	6.2% Series	M	6.2%	10/12	Now	MW (T + .35%)	$	70		$	70		$	70
179423AC2	5.875% Series – Mississippi Business Finance Corp.	G(b)	5.875%	2022	Now	100%		216			216			216
605277AC6	5.9% Series – Mississippi Business Finance Corp.	G(b)	5.9%	2022	Now	100%		103			103			103
179423AK4	6.2% Series – Claiborne County	G(b)	6.2%	2026	Now	100%		50			90			90
	Total bonds							439			479			479
OTHER LONG-TERM DEBT:
	Grand Gulf Lease Obligation 5.13%		5.13%					179			222			267
	6.29% Series F – Variable Interest Entity Note Payable		6.29%	09/13				70			70			-
	5.33% Series G – Variable Interest Entity Note Payable		5.33%	04/15				60			60			-
	Unamortized Premium and Discount – Net							(1	)		(1	)		(1	)
TOTAL LONG-TERM DEBT								747			830			745
Less Amount Due Within One Year								110			34			42
Long-Term Debt Excluding Amount Due Within One Year							$	637		$	797		$	703
Fair Value of Long-Term Debt(a)							$	583		$	612		$	480
*M = Mortgage Bond; G = Governmental Bond
Weighted-average annualized coupon rate								5.8	%		5.7	%		5.7	%

(a) The fair value excludes lease obligations of $179 million at System Energy and includes debt due within one year. Fair values are based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker / dealer quotes, and issuer spreads.

(b) Consists of pollution control revenue bonds and environmental revenue bonds.

Totals may not foot due to rounding.

36

UTILITY STATISTICAL INFORMATION

UTILITY TOTAL CAPABILITY

	OPERATED				OWNED & LEASED		OPERATED
As of December 31, 2011.	PLANTS		UNITS		(MW)(a)		(MW)
Plants that use fuel type:
Gas/Oil		27		69		14,022		14,360
Coal		3		5		2,261		3,887
Petroleum Coke		1		2		-		200
Total Fossil		31		76		16,283		18,447
Hydro		3		7		74		154
Nuclear		4		5		5,027		5,146
Total Capability		38		88		21,384		23,747

All plants that have units with multiple fuel types are in the Gas & Oil plant count.

(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.

UTILITY SELECTED OPERATING DATA

	2011			2010			2009			2008			2007
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil		30,042			26,637			21,767			24,552			24,131
Coal		14,915			15,616			15,101			15,648			15,035
Nuclear		40,102			42,339			41,851			37,994			40,988
Hydro		160			139			233			197			135
Total Net Generation		85,219			84,731			78,952			78,391			80,289
Purchased Power:
Affiliated Companies		803			738			741			817			729
Non-  affiliated Companies		32,896			33,155			30,708			32,582			33,978
Total Purchased Power		33,699			33,893			31,449			33,399			34,707
Total Sources of Energy		118,918			118,625			110,401			111,790			114,996
USES OF ENERGY (GWh)
Electric Energy Sales:
Residential		36,684			37,465			33,626			33,047			33,281
Commercial		28,720			28,831			27,476			27,340			27,408
Industrial		40,810			38,751			35,638			37,843			38,985
Governmental		2,474			2,463			2,408			2,379			2,339
Total Retail		108,688			107,510			99,148			100,609			102,013
Sales for Resale		4,111			4,372			4,862			5,401			6,145
Unbilled Energy		(131	)		(173	)		631			(264	)		277
Total Electric Energy Sales		112,668			111,709			104,641			105,746			108,435
Line Losses and Company Usage		6,250			6,916			5,760			6,044			6,561
Total Uses of Energy		118,918			118,625			110,401			111,790			114,996
Peak Demand (MW)		22,387			21,799			21,009			21,241			22,001
Operational Summer Capacity at Peak (MW)		23,979			24,310			23,578			24,844			23,996
Annual System Load Factor (%)		60			62			60			59			59
Retail Electric Sales Growth Rate (%)		1.1			8.4			(1.5	)		(1.4	)		5.5
Retail Electric Sales Weather-Adjusted Growth Rate (%)		2.0			4.3			(1.5	)		(0.5	)		6.0
Regional Gross Domestic Product Rate (%)		2.7			3.5			(2.4	)		(0.2	)		3.1
National Gross Domestic Product Rate (%)		1.7			3.0			(3.5	)		(0.3	)		1.9
Average Fuel Cost (cents/KWh)
Natural Gas		4.85			5.39			5.64			10.28			8.05
Nuclear Fuel		0.81			0.78			0.66			0.60			0.57
Coal		2.31			2.00			2.04			2.06			1.86
Fuel Oil		-			-			-			19.45			14.13
Purchased Power		4.59			5.28			5.29			7.92			6.27

Totals may not foot due to rounding.

37

UTILITY STATISTICAL INFORMATION

2011 CONSOLIDATING UTILITY ELECTRIC STATISTICAL INFORMATION

	EAI			EGSL			ELL		EMI			ENOI			ETI			SERI		ELIMINATIONS			TOTAL			%
ELECTRIC OPERATING REVENUES ($ thousands)
Residential		755,807			479,060			829,663		490,088			175,994			638,161			-		-			3,368,773			39	%
Commercial		449,756			416,321			549,142		401,276			153,824			368,614			-		(5,905	)		2,333,028			27	%
Industrial		421,384			490,378			867,491		145,792			29,800			351,731			-		-			2,306,576			27	%
Governmental		19,711			20,925			41,900		37,302			59,840			25,955			-		-			205,633			2	%
Total Retail		1,646,658			1,406,684			2,288,196		1,074,458			419,458			1,384,461			-		(5,905	)		8,214,010			95	%
Sales for Resale		375,127			614,429			145,009		131,334			95,704			336,555			563,390		(2,046,019	)		215,529			2	%
Other		62,525			48,435			75,710		60,678			14,066			36,183			21		(53,642	)		243,978			3	%
Total		2,084,310			2,069,548			2,508,915		1,266,470			529,228			1,757,199			563,411		(2,105,566	)		8,673,517			100	%
FUEL REVENUES (included in above revenues)
Residential		147,763			186,547			332,827		181,581			59,406			231,058			-		-			1,139,182			34	%
Commercial		110,070			178,013			218,649		154,748			60,829			166,223			-		-			888,532			27	%
Industrial		126,854			292,036			535,592		69,808			15,310			214,474			-		-			1,254,074			37	%
Governmental		4,965			7,453			16,595		12,861			24,790			10,836			-		-			77,500			2	%
Total Retail		389,652			664,049			1,103,663		418,998			160,335			622,591			-		-			3,359,288			100	%
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil		1,078			3,547			10,506		5,978			2,412			6,521			-		-			30,042			25	%
Coal		7,636			2,605			-		2,749			-			1,925			-		-			14,915			13	%
Nuclear		14,194			7,686			8,929		-			-			-			9,293		-			40,102			34	%
Hydro		160			-			-		-			-			-			-		-			160			0	%
Total Net Generation		23,068			13,838			19,435		8,727			2,412			8,446			9,293		-			85,219			72	%
Purchased Power:
Affiliated Companies		4,280			6,446			7,484		5,080			3,650			6,546			-		(32,683	)		803			0	%
Non-affiliated Companies		4,035			10,007			8,682		1,524			489			8,159			-		-			32,896			28	%
Total Purchased Power		8,315			16,453			16,166		6,604			4,139			14,705			-		(32,683	)		33,699			28	%
Total Sources of Energy		31,383			30,291			35,601		15,331			6,551			23,151			9,293		(32,683	)		118,918			100	%
USES OF ENERGY (GWh)
Electric Energy Sales:
Residential		8,229			5,383			9,303		5,848			1,888			6,034			-		-			36,684			34	%
Commercial		6,051			5,239			6,155		4,985			1,939			4,433			-		(81	)		28,720			26	%
Industrial		7,029			9,041			15,813		2,326			498			6,102			-		-			40,810			38	%
Governmental		275			222			473		415			795			294			-		-			2,474			2	%
Total Retail		21,584			19,885			31,744		13,574			5,120			16,863			-		(81	)		108,688			100	%
Sales for Resale		8,197			9,608			2,330		763			1,186			5,416			9,293		(32,683	)		4,111			-
Unbilled Energy		(49	)		(39	)		38		(69	)		(1	)		(11	)		-		-			(131	)		-
Total Electric Energy Sales		29,732			29,454			34,112		14,268			6,305			22,268			9,293		(32,764	)		112,668			-
Line Losses and Company Usage		1,651			837			1,489		1,063			246			883			-		81			6,250			-
Total Uses of Energy		31,383			30,291			35,601		15,331			6,551			23,151			9,293		(32,683	)		118,918			-
AVERAGE ELECTRIC REVENUE (cents/KWh)
Residential		9.18			8.90			8.92		8.38			9.32			10.58			-		-			9.18			-
Commercial		7.43			7.95			8.92		8.05			7.93			8.32			-		-			8.12			-
Industrial		5.99			5.42			5.49		6.27			5.98			5.76			-		-			5.65			-
Governmental		7.17			9.43			8.86		8.99			7.53			8.83			-		-			8.31			-
NUMBER OF RETAIL ELECTRIC CUSTOMERS
(as of December 31, 2011)
Residential		582,813			328,718			580,627		366,697			142,680			360,909			-		-			2,362,444			86	%
Commercial		88,895			50,277			76,130		62,762			13,920			44,760			-		-			336,744			12	%
Industrial		20,402			3,278			6,908		3,488			2,288			4,809			-		-			41,173			1	%
Governmental		693			1,615			5,767		4,358			1,738			2,248			-		-			16,419			1	%
Total Retail Customers		692,803			383,888			669,432		437,305			160,626			412,726			-		-			2,756,780			100	%

Totals may not foot due to rounding.

38

UTILITY STATISTICAL INFORMATION

ENTERGY ARKANSAS, INC.

	2011			2010			2009		2008		2007
ELECTRIC OPERATING REVENUES ($ thousands)
Residential		755,807			773,012			768,500		755,780		689,885
Commercial		449,756			441,387			474,543		462,599		408,561
Industrial		421,384			414,791			433,321		461,486		406,984
Governmental		19,711			19,524			21,731		21,043		18,972
Total Retail		1,646,658			1,648,714			1,698,095		1,700,908		1,524,402
Sales for Resale		375,127			379,894			452,424		572,350		458,372
Other		62,525			53,839			60,743		55,091		50,191
Total Electric Operating Revenues		2,084,310			2,082,447			2,211,263		2,328,349		2,032,965
FUEL REVENUES (included in above revenues)
Residential		147,763			91,412			127,137		142,415		124,582
Commercial		110,070			65,809			95,959		111,657		92,056
Industrial		126,854			75,939			104,226		135,772		115,077
Governmental		4,965			2,976			4,416		5,129		4,308
Total Retail Fuel Revenues		389,652			236,136			331,738		394,973		336,023
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil		1,078			984			1,003		300		89
Coal		7,636			8,233			7,955		8,273		7,935
Nuclear		14,194			15,023			15,168		14,168		15,486
Hydro		160			139			233		197		135
Total Net Generation		23,068			24,379			24,359		22,938		23,645
Purchased Power:
Affiliated Companies		4,280			3,887			3,776		3,480		3,636
Non-affiliated Companies		4,035			4,508			4,968		6,164		5,790
Total Purchased Power		8,315			8,395			8,744		9,644		9,426
Total Sources of Energy		31,383			32,774			33,103		32,582		33,071
USES OF ENERGY (GWh)
Electric Energy Sales:
Residential		8,229			8,501			7,464		7,678		7,725
Commercial		6,051			6,144			5,817		5,875		5,945
Industrial		7,029			7,082			6,376		7,211		7,424
Governmental		275			277			269		274		277
Total Retail		21,584			22,004			19,926		21,038		21,371
Sales for Resale		8,197			8,703			11,611		10,049		9,836
Unbilled Energy		(49	)		(123	)		111		13		35
Total Electric Energy Sales		29,732			30,584			31,648		31,100		31,242
Line Losses and Company Usage		1,651			2,190			1,455		1,482		1,829
Total Uses of Energy		31,383			32,774			33,103		32,582		33,071
AVERAGE ELECTRIC REVENUE (cents/KWh)
Residential		9.18			9.09			10.30		9.84		8.93
Commercial		7.43			7.18			8.16		7.87		6.87
Industrial		5.99			5.86			6.80		6.40		5.48
Governmental		7.17			7.05			8.08		7.68		6.85
NUMBER OF RETAIL ELECTRIC CUSTOMERS
(as of December 31)
Residential		582,813			582,557			580,672		578,664		576,975
Commercial		88,895			88,725			87,929		87,322		86,532
Industrial		20,402			20,605			20,118		20,922		20,040
Governmental		693			674			661		640		618
Total Retail Customers		692,803			692,561			689,380		687,548		684,165

Totals may not foot due to rounding.

39

UTILITY STATISTICAL INFORMATION

ENTERGY ARKANSAS, INC.

GENERATION PORTFOLIO

				OWNED & LEASED CAPABILITY (MW)(a)			PLANT AVG BTU PER KWH											TOTAL PLANT – 2011
			COMMER- CIAL OPER- ATION						Emissions									NET			EXPEN- SES PER NET MWH			TOTAL PRODUCTION EXPENSE ($000)
PLANT	UNIT	OWNER- SHIP			FUEL TYPE	PURPOSE	NET GENER- ATION		SO2 (tons)		NOx (tons)		CO2 (tons)		Hg(b) (lbs)		TECHNOLOGY(c)	GENER- ATION (MWH)
Cecil Lynch	2	100%	1949	-	Gas/Oil	Reserve		14,090		-		-		-		-	-		112,605			92.9			10,457
	3	100%	1954	110	Gas/Oil	Peaking				1		226		94,139		-	-
Harvey Couch	1	100%	1943	-	Gas/Oil	Retired(e)		15,150		-		-		-		-	-		21,365			178.6			3,816
	2	100%	1954	123	Gas/Oil	Peaking				-		23		18,035		-	-
Lake Catherine	1	100%	1950	47	Gas/Oil	Peaking		14,310		-		1.5		406		-	-		105,589			227.0			23,969
	2	100%	1950	45	Gas/Oil	Peaking				-		0.6		67		-	-
	3	100%	1953	96	Gas/Oil	Peaking				-		1.9		461		-	-
	4	100%	1970	524	Gas/Oil	Peaking				1		145		89,074		-	-
Hamilton Moses	1	100%	1951	-	Gas/Oil	Reserve		-		-		-		-		-	-		-			-			381
	2	100%	1951	-	Gas/Oil	Reserve				-		-		-		-	-
Mabelvale	1	100%	1970	14	Gas/Oil	Peaking		15,020		-		-		-		-	-		35,453			99.9			3,541
	2	100%	1970	14	Gas/Oil	Peaking				-		-		-		-	-
	3	100%	1970	14	Gas/Oil	Peaking				-		-		-		-	-
	4	100%	1970	14	Gas/Oil	Peaking				-		-		-		-	-
Robert Ritchie	1	100%	1961	-	Gas/Oil	Reserve		-		-		-		-		-	-		(90	)		(9,416.5	)		847
	3	100%	1970	16	Gas/Oil	Peaking				-		-		-		-	-		-			-			-
Ouachita	1	100%	2002	255	Gas	Intermediate		7,950		1		27		164,640		-	Dry LNB, SCR		802,662			45.2			36,250
	2	100%	2002	257	Gas	Intermediate				1		27		183,652		-	Dry LNB, SCR
Independence	1	31.5%	1983	263	Coal	Base		10,430		4,822		2,209		1,888,632		71	OFA, ESP		1,739,125			25.4			44,240
White Bluff	1	57%	1980	465	Coal	Base		10,280		8,560		4,144		3,133,348		117	OFA, ESP		5,896,903			25.9			152,457
	2	57%	1981	481	Coal	Base				9,500		4,984		3,503,552		131	OFA, ESP
Cecil Lynch	Diesel	100%	1967	5	Oil	Peaking		-		-		-		-		-			-			-			36
Carpenter	1	100%	1932	31	Hydro	Peaking		-		-		-		-		-	-		125,724			8.4			1,055
	2	100%	1932	31	Hydro	Peaking				-		-		-		-	-
Remmel	1	100%	1925	4	Hydro	Peaking		-		-		-		-		-	-		33,944			27.6			936
	2	100%	1925	4	Hydro	Peaking				-		-		-		-	-
	3	100%	1925	4	Hydro	Peaking				-		-		-		-	-
Arkansas
Nuclear One	1	100%	1974	834	Nuclear PWR(d)	Base		10,328		-		-		-		-	-		14,194,445			21.1			299,399
	2	100%	1980	989	Nuclear PWR(d)	Base				-		-		-		-	-
Total				4,640															23,067,725			25.0			577,386

(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel

(assuming no curtailments) that each station was designed to utilize.

(b) Mercury emissions calculated using 2011 unit heat input and 3.92 x 10-6 lb hg/MMBtu emissiom rate for coal plants and 8.0 x 10-10 lb hg/MMBtu emission rate for natural gas plants.

(c) Installed NOx and particulate matter emission control devices: Combustion Modification/ Fuel Reburning (Combus Mod / Fuel Reburn), Dry Low NOx Burners (Dry LNB), Electrostatic Precipitator (ESP), Low Nox Burners with Closed-coupled Overfire Air (LNB w/ Closed-coupled OFA), Low NOx Burners with Separated Overfire Air (LNB w/ Sep OFA), Low NOx Burner with Overfire Air (LNB w/ OFA), Overfire Air (OFA), Selective Catalytic Reduction (SCR) or Steam Injection. Currently have no SO₂, CO₂ or Mercury Control equipment operating on any unit.

(d) PWR = Pressurized Water Reactor.

(e) Harvey Couch Unit 1 was officially retired on March 18, 2011.

Calculations may differ due to rounding.

ENTERGY GULF STATES, INC.

HISTORICAL DATA PRIOR TO SEPARATION^(a)

	2007
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil		7,669
Coal		4,074
Nuclear		7,188
Hydro		-
Total Net Generation		18,931
Purchased Power:
Affiliated Companies		5,514
Non-affiliated Companies		17,658
Total Purchased Power		23,172
Total Sources of Energy		42,103
USES OF ENERGY (GWh)
Electric Energy Sales:
Louisiana
Residential		4,934
Commercial		4,895
Industrial		9,101
Governmental		204
Texas
Residential		5,281
Commercial		4,085
Industrial		5,911
Governmental		244
Total Retail		34,655
Sales for Resale		5,388
Unbilled Energy		125
Total Electric Energy Sales		40,168
Line Losses and Company Usage		1,935
Total Uses of Energy		42,103

(a) 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, Inc., and the other operating under the sole retail jurisdiction of the LPSC, Entergy Gulf States Louisiana, L.L.C., Entergy Gulf States Louisiana, L.L.C. is the successor for financial reporting purposes to Entergy Gulf States, Inc. Certain historical data by separate company is unavailable.

Totals may not foot due to rounding.

40

UTILITY STATISTICAL INFORMATION

ENTERGY GULF STATES LOUISIANA, L.L.C.^(a)

	2011			2010			2009		2008			2007
ELECTRIC OPERATING REVENUES ($ thousands)
Residential		479,060			498,319			393,490		553,527			497,782
Commercial		416,321			426,342			354,038		520,214			452,930
Industrial		490,378			488,974			383,272		672,213			620,472
Governmental		20,925			20,350			17,625		24,964			21,710
Total Retail		1,406,684			1,433,985			1,148,425		1,770,918			1,592,894
Sales for Resale		614,429			541,219			579,358		824,404			REFER TO PAGE 40
Other		48,435			40,506			48,827		37,630
Total Electric Operating Revenues		2,069,548			2,015,710			1,776,610		2,632,952
FUEL REVENUES (included in above revenues)
Residential		186,547			193,863			177,483		345,071			277,105
Commercial		178,013			182,546			175,960		343,938			271,015
Industrial		292,036			292,789			251,212		546,603			476,015
Governmental		7,453			7,251			7,341		14,572			11,120
Total Retail Fuel Revenues		664,049			676,449			611,996		1,250,184			1,035,255
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil		3,547			2,533			1,705		1,951			REFER TO PAGE 40
Coal		2,605			2,535			2,472		2,615
Nuclear		7,686			8,363			7,836		6,334
Hydro		-			-			-		-
Total Net Generation		13,838			13,431			12,013		10,900
Purchased Power:
Affiliated Companies		6,446			7,021			6,768		7,725
Non-affiliated Companies		10,007			10,437			9,720		9,607
Total Purchased Power		16,453			17,458			16,488		17,332
Total Sources of Energy		30,291			30,889			28,501		28,232
USES OF ENERGY (GWh)
Electric Energy Sales:
Residential		5,383			5,538			5,090		4,888			4,934
Commercial		5,239			5,274			5,058		4,973			4,895
Industrial		9,041			8,801			7,601		8,416			9,101
Governmental		222			210			213		215			204
Total Retail		19,885			19,823			17,962		18,492			19,134
Sales for Resale		9,608			10,221			9,630		9,014			REFER TO PAGE 40
Unbilled Energy		(39	)		(51	)		149		(138	)
Total Electric Energy Sales		29,454			29,993			27,741		27,368
Line Losses and Company Usage		837			896			760		864
Total Uses of Energy		30,291			30,889			28,501		28,232
AVERAGE ELECTRIC REVENUE (cents/KWh)
Residential		8.90			9.00			7.73		11.32			10.09
Commercial		7.95			8.08			7.00		10.46			9.25
Industrial		5.42			5.56			5.04		7.99			6.82
Governmental		9.43			9.69			8.27		11.61			10.64
NUMBER OF RETAIL ELECTRIC CUSTOMERS
(as of December 31)
Residential		328,718			326,497			324,285		320,745			317,001
Commercial		50,277			49,886			49,319		48,636			47,749
Industrial		3,278			3,265			3,436		3,761			4,320
Governmental		1,615			1,627			1,652		1,666			1,642
Total Retail Customers		383,888			381,275			378,692		374,808			370,712

(a) 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, Inc., and the other operating under the sole retail jurisdiction of the LPSC, Entergy Gulf States Louisiana, L.L.C., Entergy Gulf States Louisiana, L.L.C. is the successor for financial reporting purposes to Entergy Gulf States, Inc. Certain historical data by separate company is unavailable. Page 40 reflects historical data prior to the separation.

Totals may not foot due to rounding.

41

UTILITY STATISTICAL INFORMATION

ENTERGY TEXAS, INC. ^(a)

	2011			2010		2009		2008			2007
ELECTRIC OPERATING REVENUES ($ thousands)
Residential		638,161			558,733		533,146		606,133			544,254
Commercial		368,614			320,935		336,876		416,798			364,322
Industrial		351,731			305,455		332,303		489,165			414,036
Governmental		25,955			22,527		22,797		26,872			23,583
Total Retail		1,384,461			1,207,650		1,225,122		1,538,968			1,346,195
Sales for Resale		336,555			449,233		303,682		441,314			REFER TO PAGE 40
Other		36,183			33,548		35,019		31,976
Total Electric Operating Revenues		1,757,199			1,690,431		1,563,823		2,012,258
FUEL REVENUES (included in above revenues)
Residential		231,058			228,693		250,230		328,397			281,118
Commercial		166,223			164,098		186,662		255,759			213,574
Industrial		214,474			210,357		229,164		363,208			298,219
Governmental		10,836			10,333		11,479		15,446			12,946
Total Retail Fuel Revenues		622,591			613,481		677,535		962,810			805,857
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil		6,521			6,355		6,184		6,046			REFER TO PAGE 40
Coal		1,925			1,874		1,827		1,933
Nuclear		-			-		-		-
Hydro		-			-		-		-
Total Net Generation		8,446			8,229		8,011		7,979
Purchased Power:
Affiliated Companies		6,546			7,537		6,349		5,696
Non-affiliated Companies		8,159			6,478		6,034		6,530
Total Purchased Power		14,705			14,016		12,383		12,226
Total Sources of Energy		23,151			22,245		20,394		20,205
USES OF ENERGY (GWh)
Electric Energy Sales:
Residential		6,034			5,958		5,453		5,245			5,280
Commercial		4,433			4,271		4,165		4,092			4,085
Industrial		6,102			5,642		5,570		5,948			5,911
Governmental		294			271		258		248			246
Total Retail		16,863			16,142		15,446		15,533			15,522
Sales for Resale		5,416			5,058		3,861		3,858			REFER TO PAGE 40
Unbilled Energy		(11	)		10		104		(64	)
Total Electric Energy Sales		22,268			21,210		19,411		19,327
Line Losses and Company Usage		883			1,035		983		878
Total Uses of Energy		23,151			22,245		20,394		20,205
AVERAGE ELECTRIC REVENUE (cents/KWh)
Residential		10.58			9.38		9.78		11.56			10.31
Commercial		8.32			7.51		8.09		10.19			8.92
Industrial		5.76			5.41		5.97		8.22			7.00
Governmental		8.83			8.31		8.84		10.84			9.63
NUMBER OF RETAIL ELECTRIC CUSTOMERS
(as of December 31)
Residential		360,909			356,999		352,682		346,533			344,704
Commercial		44,760			44,080		43,375		42,005			41,963
Industrial		4,809			4,815		4,896		4,532			4,934
Governmental		2,248			2,213		2,159		2,112			2,085
Total Retail Customers		412,726			408,107		403,112		395,182			393,686

(a) 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, Inc., and the other operating under the sole retail jurisdiction of the LPSC, Entergy Gulf States Louisiana, L.L.C., Entergy Gulf States Louisiana, L.L.C. is the successor for financial reporting purposes to Entergy Gulf States, Inc. Certain historical data by separate company is unavailable. Page 40 reflects historical data prior to the separation.

Totals may not foot due to rounding.

42

UTILITY STATISTICAL INFORMATION

ENTERGY GULF STATES LOUISIANA, L.L.C.

GENERATION PORTFOLIO

							PLANT AVG BTU PER KWH											TOTAL PLANT – 2011
			COMMER-	OWNED &				Emissions										NET		EXPEN-		TOTAL
PLANT	UNIT	OWNER- SHIP	CIAL OPER- ATION	LEASED CAPABILITY (MW)(a)	FUEL TYPE	PURPOSE	NET GENER- ATION	SO2 (tons)		NOx (tons)		CO2 (tons)		Hg(b) (lbs)		TECHNOLOGY(c)		GENER- ATION (MWH)		SES PER NET MWH		PRODUCTION EXPENSE ($000)
LA Station 2 (d)	10	100%	1950	-	Gas	Reserve	-		-		-		-		-		-		-		-		427
	11	100%	1950	-	Gas	Reserve			-		-		-		-		-
	12	100%	1953	-	Gas	Reserve			-		-		-		-		-
Willow Glen	1	100%	1960	152	Gas/Oil	Peaking	11,500		1		218		172,451		-		-		1,419,842		58.4		82,961
	2	100%	1964	195	Gas/Oil	Peaking			-		25		20,233		-		-
	3	100%	1968	-	Gas	Reserve			-		-		-		-		ESP
	4	100%	1973	470	Gas/Oil	Peaking			3		1,376		626,649		-		-
	5	100%	1976	-	Gas/Oil	Reserve			-		-		-		-		-
Roy S. Nelson	3	100%	1960	145	Gas/Oil	Intermediate	12,910		1		281		213,883		-		-		1,334,041		61.9		82,612
	4	100%	1970	450	Gas/Oil	Intermediate			4		832		787,838		-		-
Calcasieu	1	100%	2000	150	Gas	Peaking	11,150		1		67		91,225		-		Dry LNB		314,614		58.5		18,393
	2	100%	2001	160	Gas	Peaking			1		90		120,146		-		Dry LNB
Ouachita	3	100%	2002	258	Gas	Intermediate	7,430		1		32		197,403		-		Dry LNB, SCR		478,674		41.2		19,726
Roy S. Nelson	6	40%	1982	221	Coal	Base	10,910		5,796		1,460		1,788,627		65		LNB w/ Sep OFA, ESP		1,511,046		38.2		57,650
Big Cajun 2	3	24%	1983	142	Coal	Base	10,330		3,172		802		1,115,364		42		LNB w/ OFA, ESP		1,093,775		25.4		27,803
River Bend	1	100%(e)	1986	974	Nuclear BWR(f)	Base	10,769		-		-		-		-		-		7,686,445		24.5		188,286
Total				3,317															13,838,437		34.5		477,857

(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.

(b) Mercury emissions calculated using 2011 unit heat input and 3.92 x 10-6 lb hg/MMBtu emissiom rate for coal plants and 8.0 x 10-10 lb hg/MMBtu emission rate for natural gas plants.

(c) Installed NOx and particulate matter emission control devices: Combustion Modification/ Fuel Reburning (Combus Mod / Fuel Reburn), Dry Low NOx Burners (Dry LNB), Electrostatic Precipitator (ESP), Low Nox Burners with Closed-coupled Overfire Air (LNB w/ Closed-coupled OFA), Low NOx Burners with Separated Overfire Air (LNB w/ Sep OFA), Low NOx Burner with Overfire Air (LNB w/ OFA), Overfire Air (OFA), Selective Catalytic Reduction (SCR) or Steam Injection. Currently have no SO₂, CO₂ or Mercury Control equipment operating on any unit.

(d) EGSL also owns and operates LA Station 1 units 1a, 2a, 3a and 4a; these units are under a long-term contract with an external 3rd party, which owns all of the output of these units.

(e) 30% of River Bend is not subject to rate regulation by the Public Utility Commission of Texas, the Louisiana Public Service Commission, nor various municipal authorities.

(f) BWR = Boiling Water Reactor.

Calculations may differ due to rounding.

ENTERGY TEXAS, INC.

GENERATION PORTFOLIO

							PLANT AVG BTU PER KWH										TOTAL PLANT – 2011
			COMMER-	OWNED &				Emissions									NET		EXPEN-		TOTAL
PLANT	UNIT	OWNER- SHIP	CIAL OPER- ATION	LEASED CAPABILITY (MW)(a)	FUEL TYPE	PURPOSE	NET GENER- ATION	SO2 (tons)		NOx (tons)		CO2 (tons)		Hg(b) (lbs)		TECHNOLOGY(c)	GENER- ATION (MWH)		SES PER NET MWH		PRODUCTION EXPENSE ($000)
Roy S. Nelson	6	30%	1982	164	Coal	Base	10,910		4,283		1,079		1,322,028		48	LNB w/ Sep OFA, ESP		1,116,859		38.9		43,403
Big Cajun 2	3	18%	1983	105	Coal	Base	10,320		2,345		593		824,399		31	LNB w/ OFA, ESP		808,443		25.3		20,491
Lewis Creek	1	100%	1970	230	Gas/Oil	Intermediate	11,360		4		92		689,325		-	SCR		1,719,362		54.4		93,556
	2	100%	1971	230	Gas/Oil	Intermediate			3		85		509,486		-	SCR
Sabine	1	100%	1962	212	Gas/Oil	Intermediate	11,370		2		661		451,190		-	-		4,801,434		53.2		255,630
	2	100%	1962	212	Gas/Oil	Intermediate			2		518		347,665		-	-
	3	100%	1966	390	Gas/Oil	Intermediate			3		679		569,384		-	LNB w/ Sep OFA
	4	100%	1974	525	Gas	Intermediate			7		1,406		1,310,391		-	Combus Mod / Fuel Reburn
	5	100%	1979	470	Gas/Oil	Intermediate			2		309		453,663		-	LNB w/ Closed- coupled OFA
Total				2,538														8,446,097		48.9		413,080

(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.

(b) Mercury emissions calculated using 2011 unit heat input and 3.92 x 10-6 lb hg/MMBtu emissiom rate for coal plants and 8.0 x 10-10 lb hg/MMBtu emission rate for natural gas plants.

(c) Installed NOx and particulate matter emission control devices: Combustion Modification/ Fuel Reburning (Combus Mod / Fuel Reburn), Dry Low NOx Burners (Dry LNB), Electrostatic Precipitator (ESP), Low Nox Burners with Closed-coupled Overfire Air (LNB w/ Closed-coupled OFA), Low NOx Burners with Separated Overfire Air (LNB w/ Sep OFA), Low NOx Burner with Overfire Air (LNB w/ OFA), Overfire Air (OFA), Selective Catalytic Reduction (SCR) or Steam Injection. Currently have no SO₂, CO₂ or Mercury Control equipment operating on any unit.

Calculations may differ due to rounding.

43

UTILITY STATISTICAL INFORMATION

ENTERGY LOUISIANA, LLC

	2011		2010		2009		2008			2007
ELECTRIC OPERATING REVENUES ($ thousands)
Residential		829,663		840,011		669,084		967,445			853,780
Commercial		549,142		543,308		456,274		659,880			578,025
Industrial		867,491		817,454		664,377		1,061,887			871,853
Governmental		41,900		42,124		35,760		51,064			43,550
Total Retail		2,288,196		2,242,897		1,825,495		2,740,276			2,347,208
Sales for Resale		145,009		225,011		256,596		261,218			318,001
Other		75,710		70,858		101,495		49,800			72,343
Total Electric Operating Revenues		2,508,915		2,538,766		2,183,586		3,051,294			2,737,552
FUEL REVENUES (included in above revenues)
Residential		332,827		360,847		287,909		530,363			415,883
Commercial		218,649		231,104		194,759		358,257			280,200
Industrial		535,592		523,895		435,112		780,147			614,448
Governmental		16,595		18,067		15,388		27,782			21,305
Total Retail Fuel Revenues		1,103,663		1,133,913		933,168		1,696,549			1,331,836
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil		10,506		9,429		7,090		8,930			8,784
Coal		-		-		-		-			-
Nuclear		8,929		10,276		8,949		9,037			9,893
Hydro		-		-		-		-			-
Total Net Generation		19,435		19,705		16,039		17,967			18,677
Purchased Power:
Affiliated Companies		7,484		5,783		7,818		5,996			6,025
Non-affiliated Companies		8,682		9,614		7,644		7,511			7,484
Total Purchased Power		16,166		15,397		15,462		13,507			13,509
Total Sources of Energy		35,601		35,102		31,501		31,474			32,186
USES OF ENERGY (GWh)
Electric Energy Sales:
Residential		9,303		9,533		8,684		8,487			8,646
Commercial		6,155		6,164		5,867		5,784			5,848
Industrial		15,813		14,473		13,386		13,162			13,209
Governmental		473		479		459		459			446
Total Retail		31,744		30,649		28,396		27,892			28,149
Sales for Resale		2,330		2,961		1,621		2,233			2,411
Unbilled Energy		38		27		164		(118	)		124
Total Electric Energy Sales		34,112		33,637		30,181		30,007			30,684
Line Losses and Company Usage		1,489		1,465		1,320		1,467			1,502
Total Uses of Energy		35,601		35,102		31,501		31,474			32,186
AVERAGE ELECTRIC REVENUE (cents/KWh)
Residential		8.92		8.81		7.70		11.40			9.87
Commercial		8.92		8.81		7.78		11.41			9.88
Industrial		5.49		5.65		4.96		8.07			6.60
Governmental		8.86		8.79		7.79		11.13			9.76
NUMBER OF RETAIL ELECTRIC CUSTOMERS
(as of December 31)
Residential		580,627		578,466		575,388		571,301			568,893
Commercial		76,130		75,493		74,608		73,617			73,012
Industrial		6,908		6,971		7,247		7,592			8,374
Governmental		5,767		5,704		5,539		5,387			5,229
Total Retail Customers		669,432		666,634		662,782		657,897			655,508

Totals may not foot due to rounding.

44

UTILITY STATISTICAL INFORMATION

ENTERGY LOUISIANA, LLC

GENERATION PORTFOLIO

			COMMER- CIAL OPER- ATION	OWNED & LEASED CAPABILITY (MW)(a)			PLANT AVG BTU PER KWH NET GENER- ATION							TOTAL PLANT – 2011
								Emissions						NET GENER- ATION (MWH)		EXPEN- SES PER NET MWH		TOTAL PRODUCTION EXPENSE ($000)
PLANT	UNIT	OWNER- SHIP			FUEL TYPE	PURPOSE		SO2 (tons)	NOx (tons)	CO2 (tons)	Hg(b) (lbs)	TECHNOLOGY(c)
Acadia	2	100%	2002	578	Gas	Intermediate	7,540	2	37	417,816	-		SCR		1,243,351		41.9		52,034
Buras	8	100%	1971	12	Gas/Oil	Peaking	35,980	-	-	-	-		-		9,813		336.2		3,299
Little Gypsy	1	100%	1961	238	Gas/Oil	Intermediate	12,620	1	378	217,713	-		-		1,797,288		71.8		128,961
	2	100%	1966	410	Gas/Oil	Intermediate		2	365	404,604	-		-
	3	100%	1969	522	Gas/Oil	Intermediate		3	2,086	636,336	-		-
Monroe	10	100%	1961	-	Gas	Retired(e)	-	-	-	-	-		-		-		-		-
	11	100%	1965	-	Gas	Retired(e)		-	-	-	-		-
	12	100%	1968	-	Gas	Retired(e)		-	-	-	-		-
Ninemile Point	1	100%	1951	-	Gas/Oil	Retired(f)	10,930	-	1	1,906	-		-		4,439,683		53.9		239,394
	2	100%	1953	-	Gas/Oil	Retired(f)		-	-	-	-		-
	3	100%	1955	125	Gas/Oil	Intermediate		1	212	154,719	-		-
	4	100%	1971	500	Gas/Oil	Intermediate		6	2,531	1,104,973	-		-
	5	100%	1973	740	Gas/Oil	Intermediate		8	3,731	1,606,035	-		-
Perryville	1	100%	2002	535	Gas	Intermediate	7,360	4	113	882,309	-		Dry LNB, SCR		1,948,323		41.3		80,532
	2	100%	2001	156	Gas	Peaking		-	1	1,876	-		Dry LNB
Sterlington	6	100%	1958	-	Gas/Oil	Reserve	13,160	-	-	-	-		-		23,109		167.4		3,868
	7	100%	1974	174	Gas/Oil	Peaking		1	53	17,247	-		-
Waterford	1	100%	1975	411	Gas/Oil	Intermediate	13,450	69	333	354,835	-		-		1,044,471		79.7		83,271
	2	100%	1975	411	Gas/Oil	Intermediate		45	453	488,524	-		-
	4	100%	2009	31	Oil	Peaking	-	-	1	1,139	-		Steam Injection		-		-		-
Waterford	3	100%	1985	1,159	Nuclear PWR(d)	Base	10,898	-	-	-	-		-		8,928,530		22.5		201,083
Total				6,002											19,434,568		40.8		792,442

(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.

(b) Mercury emissions calculated using 2011 unit heat input and 3.92 x 10-6 lb hg/MMBtu emissiom rate for coal plants and 8.0 x 10-10 lb hg/MMBtu emission rate for natural gas plants.

(c) Installed NOx and particulate matter emission control devices: Combustion Modification/ Fuel Reburning (Combus Mod / Fuel Reburn), Dry Low NOx Burners (Dry LNB), Electrostatic Precipitator (ESP), Low Nox Burners with Closed-coupled Overfire Air (LNB w/ Closed-coupled OFA), Low NOx Burners with Separated Overfire Air (LNB w/ Sep OFA), Low NOx Burner with Overfire Air (LNB w/ OFA), Overfire Air (OFA), Selective Catalytic Reduction (SCR) or Steam Injection. Currently have no SO₂, CO₂ or Mercury Control equipment operating on any unit.

(d) PWR = Pressurized Water Reactor.

(e) Monroe Units 10, 11 & 12 were officially retired on October 14, 2011.

(f) Ninemile Point Units 1 & 2 were officially retired on September 23, 2011.

Calculations may differ due to rounding.

45

UTILITY STATISTICAL INFORMATION

ENTERGY MISSISSIPPI, INC.

	2011			2010			2009		2008		2007
ELECTRIC OPERATING REVENUES ($ thousands)
Residential		490,088			508,571			466,632		555,913		500,097
Commercial		401,276			405,577			395,444		481,878		427,545
Industrial		145,792			144,581			146,608		199,453		185,119
Governmental		37,302			37,754			37,740		44,336		40,417
Total Retail		1,074,458			1,096,483			1,046,424		1,281,580		1,153,178
Sales for Resale		131,334			87,670			79,408		131,270		172,919
Other		60,678			48,769			54,275		51,849		47,914
Total Electric Operating Revenues		1,266,470			1,232,922			1,180,107		1,464,699		1,374,011
FUEL REVENUES (included in above revenues)
Residential		181,581			177,354			179,338		281,916		215,446
Commercial		154,748			145,950			158,937		252,867		192,289
Industrial		69,808			63,696			70,679		121,026		100,293
Governmental		12,861			12,031			13,614		21,352		16,605
Total Retail Fuel Revenues		418,998			399,031			422,568		677,161		524,633
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil		5,978			5,469			3,583		5,257		5,734
Coal		2,749			2,974			2,847		2,827		3,026
Nuclear		-			-			-		-		-
Hydro		-			-			-		-		-
Total Net Generation		8,727			8,443			6,430		8,084		8,760
Purchased Power:
Affiliated Companies		5,080			5,467			6,127		4,903		4,602
Non-affiliated Companies		1,524			1,607			1,752		2,083		2,706
Total Purchased Power		6,604			7,074			7,879		6,986		7,308
Total Sources of Energy		15,331			15,517			14,309		15,070		16,068
USES OF ENERGY (GWh)
Electric Energy Sales:
Residential		5,848			6,077			5,358		5,354		5,474
Commercial		4,985			5,000			4,756		4,841		4,872
Industrial		2,326			2,250			2,178		2,565		2,771
Governmental		415			416			405		411		421
Total Retail		13,574			13,743			12,697		13,171		13,538
Sales for Resale		763			670			528		935		1,493
Unbilled Energy		(69	)		(18	)		74		23		(22	)
Total Electric Energy Sales		14,268			14,395			13,299		14,129		15,009
Line Losses and Company Usage		1,063			1,122			1,010		941		1,059
Total Uses of Energy		15,331			15,517			14,309		15,070		16,068
AVERAGE ELECTRIC REVENUE (cents/KWh)
Residential		8.38			8.37			8.71		10.38		9.14
Commercial		8.05			8.11			8.31		9.95		8.78
Industrial		6.27			6.43			6.73		7.78		6.68
Governmental		8.99			9.08			9.32		10.79		9.60
NUMBER OF RETAIL ELECTRIC CUSTOMERS
(as of December 31)
Residential		366,697			366,722			365,804		362,649		361,725
Commercial		62,762			62,858			62,613		62,556		63,642
Industrial		3,488			3,450			2,749		2,827		3,109
Governmental		4,358			4,322			4,259		4,208		4,096
Total Retail Customers		437,305			437,352			435,425		432,240		432,572

Totals may not foot due to rounding.

46

UTILITY STATISTICAL INFORMATION

ENTERGY MISSISSIPPI, INC.

GENERATION PORTFOLIO

				OWNED & LEASED CAPABILITY (MW)(a)			PLANT AVG BTU PER KWH						TOTAL PLANT – 2011
			COMMER- CIAL OPER- ATION					Emissions					NET GENER- ATION (MWH)			EXPEN- SES PER NET MWH			TOTAL PRODUCTION EXPENSE ($000)
PLANT	UNIT	OWNER- SHIP			FUEL TYPE	PURPOSE	NET GENER- ATION	SO2 (tons)	NOx (tons)	CO2 (tons)	Hg(b) (lbs)	TECHNOLOGY(c)
Attala	1	100%	2001	455	Gas	Intermediate	7,310	3	38	547,196	-	Dry LNB, SCR		1,526,769			43.1			65,787
Baxter Wilson	1	100%	1967	500	Gas/Oil	Intermediate	11,860	136	2,976	1,276,005	-	-		2,806,390			54.9			154,070
	2	100%	1971	676	Gas/Oil	Intermediate		5	2,676	919,365	-	Combus Mod / Fuel Reburn
Delta	1	100%	1953	-	Gas/Oil	Reserve	-	-	-	-	-	-		(416	)		(3,047.0	)		1,268
	2	100%	1953	-	Gas/Oil	Reserve		-	-	-	-	-
Gerald Andrus	1	100%	1975	712	Gas/Oil	Intermediate	11,400	5	1,599	976,255	-	OFA		1,468,591			56.5			83,001
Natchez	1	100%	1951	-	Gas/Oil	Retired(d)	-	-	-	-	-	-		-			-			2
Rex Brown	1	100%	1948	-	Gas	Retired(e)	15,670	-	-	-	-	-		177,262			96.4			17,091
	3	100%	1951	70	Gas/Oil	Peaking		-	37	32,154	-	-
	4	100%	1959	209	Gas/Oil	Intermediate		1	431	172,055	-	-
	5	100%	1968	10	Oil	Peaking		-	-	-	-	-
Independence	1	25%	1983	209	Coal	Base	10,350	3,827	1,753	1,498,915	56	OFA, ESP		2,748,766			24.6			67,678
	2	25%	1984	211	Coal	Base		3,773	1,599	1,475,285	55	OFA, ESP
Total				3,052										8,727,362			44.6			388,896

(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.

(b) Mercury emissions calculated using 2011 unit heat input and 3.92 x 10-6 lb hg/MMBtu emissiom rate for coal plants and 8.0 x 10-10 lb hg/MMBtu emission rate for natural gas plants.

(c) Installed NOx and particulate matter emission control devices: Combustion Modification/ Fuel Reburning (Combus Mod / Fuel Reburn), Dry Low NOx Burners (Dry LNB), Electrostatic Precipitator (ESP), Low Nox Burners with Closed-coupled Overfire Air (LNB w/ Closed-coupled OFA), Low NOx Burners with Separated Overfire Air (LNB w/ Sep OFA), Low NOx Burner with Overfire Air (LNB w/ OFA), Overfire Air (OFA), Selective Catalytic Reduction (SCR) or Steam Injection. Currently have no SO₂, CO₂ or Mercury Control equipment operating on any unit.

(d) Natchez Unit 1 was officially retired on June 10, 2011.

(e) Rex Brown Unit 1 was officially retired on June 10, 2011.

Calculations may differ due to rounding.

47

UTILITY STATISTICAL INFORMATION

ENTERGY NEW ORLEANS, INC.

	2011			2010			2009		2008		2007
ELECTRIC OPERATING REVENUES ($ thousands)
Residential		175,994			196,391			167,794		171,584		142,497
Commercial		153,824			173,536			166,454		193,552		181,438
Industrial		29,800			35,826			37,225		48,378		46,697
Governmental		59,840			70,146			69,306		79,973		72,467
Total Retail		419,458			475,899			440,779		493,487		443,099
Sales for Resale		95,704			56,500			88,010		162,769		103,843
Other		14,066			10,703			7,196		16,684		10,516
Total Electric Operating Revenues		529,228			543,102			535,985		672,940		557,458
FUEL REVENUES (included in above revenues)
Residential		59,406			65,146			62,017		92,401		71,496
Commercial		60,829			66,088			72,121		117,282		101,932
Industrial		15,310			17,253			19,103		32,171		28,745
Governmental		24,790			28,073			31,866		50,803		42,750
Total Retail Fuel Revenues		160,335			176,560			185,107		292,657		244,923
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil		2,412			1,867			2,202		2,068		1,855
Coal		-			-			-		-		-
Nuclear		-			-			-		-		-
Hydro		-			-			-		-		-
Total Net Generation		2,412			1,867			2,202		2,068		1,855
Purchased Power:
Affiliated Companies		3,650			3,839			3,760		3,391		3,428
Non-affiliated Companies		489			511			590		687		340
Total Purchased Power		4,139			4,350			4,350		4,078		3,768
Total Sources of Energy		6,551			6,217			6,552		6,146		5,623
USES OF ENERGY (GWh)
Electric Energy Sales:
Residential		1,888			1,858			1,577		1,394		1,221
Commercial		1,939			1,899			1,813		1,774		1,763
Industrial		498			503			526		541		568
Governmental		795			809			805		774		747
Total Retail		5,120			5,069			4,721		4,483		4,299
Sales for Resale		1,186			919			1,543		1,361		1,010
Unbilled Energy		(1	)		(18	)		29		20		15
Total Electric Energy Sales		6,305			5,970			6,293		5,864		5,324
Line Losses and Company Usage		246			247			259		282		299
Total Uses of Energy		6,551			6,217			6,552		6,146		5,623
AVERAGE ELECTRIC REVENUE (cents/KWh)
Residential		9.32			10.57			10.64		12.31		11.67
Commercial		7.93			9.14			9.18		10.91		10.29
Industrial		5.98			7.12			7.08		8.94		8.22
Governmental		7.53			8.67			8.61		10.33		9.70
NUMBER OF RETAIL ELECTRIC CUSTOMERS
(as of December 31)
Residential		142,680			138,659			132,602		124,432		115,523
Commercial		13,920			14,079			13,064		12,622		12,211
Industrial		2,288			2,277			2,311		2,514		2,765
Governmental		1,738			2,079			1,747		1,381		1,308
Total Retail Customers		160,626			157,094			149,724		140,949		131,807

Totals may not foot due to rounding.

48

UTILITY STATISTICAL INFORMATION

ENTERGY NEW ORLEANS, INC.

GENERATION PORTFOLIO

								OWNED & LEASED CAPABILITY (MW)(a)				PLANT AVG BTU PER KWH NET GENER- ATION		Emissions										TOTAL PLANT – 2011
																								NET GENER- ATION (MWH)		EXPEN- SES PER NET MWH		TOTAL PRODUCTION EXPENSE ($000)
PLANT	UNIT		OWNER- SHIP			COMMER- CIAL OPER- ATION				FUEL TYPE	PURPOSE			SO2 (tons)		NOx (tons)		CO2 (tons)		Hg(b) (lbs)		TECHNOLOGY(c)
A. B. Paterson		3		100	%		1950		-	Gas/Oil	Retired		-		-		-		-		-		-		-		-		9
		4		100	%		1954		-	Gas/Oil	Retired				-		-		-		-		-
Michoud		1		100	%		1957		-	Gas/Oil	Retired(d)		11,180		-		-		151		-		-		2,411,581		49.0		118,218
		2		100	%		1963		235	Gas/Oil	Intermediate				2		706		409,867		-		-
		3		100	%		1967		529	Gas/Oil	Intermediate				6		1,696		1,225,404		-		Combus Mod / Fuel Reburn
A. B. Paterson		5		100	%		1967		-	Oil	Retired		-		-		-		-		-		-		-		-		3
Total									764																2,411,581		49.0		118,231

(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.

(b) Mercury emissions calculated using 2011 unit heat input and 3.92 x 10-6 lb hg/MMBtu emissiom rate for coal plants and 8.0 x 10-10 lb hg/MMBtu emission rate for natural gas plants.

(c) Installed NOx and particulate matter emission control devices: Combustion Modification/ Fuel Reburning (Combus Mod / Fuel Reburn), Dry Low NOx Burners (Dry LNB), Electrostatic Precipitator (ESP), Low Nox Burners with Closed-coupled Overfire Air (LNB w/ Closed-coupled OFA), Low NOx Burners with Separated Overfire Air (LNB w/ Sep OFA), Low NOx Burner with Overfire Air (LNB w/ OFA), Overfire Air (OFA), Selective Catalytic Reduction (SCR) or Steam Injection. Currently have no SO₂, CO₂ or Mercury Control equipment operating on any unit.

(d) Michoud Unit 1 was officially retired on September 23, 2011.

Calculations may differ due to rounding.

SYSTEM ENERGY RESOURCES, INC.

	2011		2010			2009		2008			2007
ELECTRIC OPERATING REVENUES ($ thousands)		563,411		558,584			554,007		528,998			553,193
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil		-		-			-		-			-
Coal		-		-			-		-			-
Nuclear		9,293		8,677			9,898		8,455			8,421
Hydro		-		-			-		-			-
Total Net Generation		9,293		8,677			9,898		8,455			8,421
Purchased Power		-		-			-		-			-
Total Sources of Energy		9,293		8,677			9,898		8,455			8,421
USES OF ENERGY (GWh)
Electric Energy Sales		9,293		8,692			9,898		8,475			8,440
Unbilled Energy		-		-			-		-			-
Line Losses and Company Usage		-		(15	)		-		(20	)		(19	)
Total Uses of Energy		9,293		8,677			9,898		8,455			8,421

Totals may not foot due to rounding.

SYSTEM ENERGY RESOURCES, INC.

GENERATION PORTFOLIO

						COMMER- CIAL OPER- ATION		OWNED & LEASED CAPABILITY (MW)(a)							PLANT AVG BTU PER KWH NET GENER- ATION		Emissions										TOTAL PLANT – 2011
																											NET GENER- ATION (MWH)		EXPEN- SES PER NET MWH		TOTAL PRODUCTION EXPENSE ($000)
PLANT	UNIT		OWNER- SHIP							FUEL TYPE			PURPOSE				SO2 (tons)		NOx (tons)		CO2 (tons)		Hg(b) (lbs)		TECHNOLOGY(c)
Grand Gulf		1		90	%		1985		1,071		Nuclear  BWR	(d)		Base		10,415		-		-		-		-		-		9,293,410		21.1		196,375
Total									1,071																			9,293,410		21.1		196,375

(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.

(b) Mercury emissions calculated using 2010 unit heat input and 3.92 x 10-6 lb hg/MMBtu emissiom rate for coal plants and 8.0 x 10-10 lb hg/MMBtu emission rate for natural gas plants.

(c) Installed NOx and particulate matter emission control devices: Combustion Modification/ Fuel Reburning (Combus Mod / Fuel Reburn), Dry Low NOx Burners (Dry LNB), Electrostatic Precipitator (ESP), Low Nox Burners with Closed-coupled Overfire Air (LNB w/ Closed-coupled OFA), Low NOx Burners with Separated Overfire Air (LNB w/ Sep OFA), Low NOx Burner with Overfire Air (LNB w/ OFA), Overfire Air (OFA), Selective Catalytic Reduction (SCR) or Steam Injection. Currently have no SO₂, CO₂ or Mercury Control equipment operating on any unit.

(d) BWR = Boiling Water Reactor.

Calculations may differ due to rounding.

49

UTILITY STATISTICAL INFORMATION

UTILITY NUCLEAR PLANT STATISTICS

The following table shows plant performance for 2007 – 2011 based on 18/24 month operating cycle.

CAPABILITY FACTOR (%)	2011	2010	2009	2008	2007
ANO	92.1	92.3	90.9	92.6	92.8
Grand Gulf	90.7	92.4	92.1	85.4	89.5
River Bend	93.4	92.7	94.2	81.8	88.1
Waterford 3	91.4	91.4	91.4	90.6	91.5
Entergy Southeast Average	91.9	92.2	91.9	88.6	90.9
Industry Average	89.3	89.3	90.2	90.7	91.1

The following table shows plant performance for 2011 and averages for four three-year periods.

PRODUCTION COST ($/MWh)(a)	2011		2008–2010		2007–2009		2006–2008		2005–2007
ANO		21.1		18.5		17.2		16.3		16.0
Grand Gulf		21.1		18.8		17.7		16.6		15.3
River Bend		24.5		23.4		22.9		22.4		20.1
Waterford 3		22.5		19.3		18.1		16.9		16.7
Entergy Southeast Average		22.0		19.6		18.5		17.5		16.7
Industry Average		23.5		20.4		19.4		18.5		17.6

(a) Fuel and non-fuel operation and maintenance expenses according to accounting standards that directly relate to the production of electricity per MWh.

INDIVIDUAL PLANT INFORMATION

ANO UNIT 1

UNIT 2

GRAND GULF

RIVER BEND

WATERFORD 3

Owner

Entergy

Entergy

System Energy-90

%

Entergy

Entergy

Arkansas

Arkansas

South Mississippi

Gulf States

Louisiana

Electric Power

Louisiana

Association-10

%

Commercial Operation Date

December 74

March 80

July 85

June 86

September 85

License Expiration Date

5/20/34

7/17/38

11/1/24

8/29/25

12/18/24

Architect/Engineer

Bechtel Power

Bechtel Power

Bechtel Power

Stone & Webster

Ebasco

Reactor Manufacturer

Babcox &

Combustion

General

General

Combustion

Wilcox

Engineering

Electric

Electric

Engineering

Reactor Type

PWR

PWR

BWR

BWR

PWR

Turbine Generator Manufacturer

Westinghouse

General Electric

Kraftwerk Union

General Electric

Westinghouse

Owned and Leased Capability (MW)(a)

834

989

1,071

974

1,159

Refueling Data:

Last Date

10/17/11 -

2/21/11 -

2/19/12 -

1/15/11 -

4/5/11 -

11/23/11

3/26/11

6/16/12

2/12/11

5/12/11

Number of Days

37

34

117

(d)

28

36

Next Scheduled Refueling

Spring 13

Fall 12

Spring 14

Spring 13

Fall 12

2011 Capability Factor (%)

92.9

91.2

90.7

93.4

91.4

($ millions as of December 31, 2011)

Net Book Value

1,171

(b)

1,314

1,479

(c)

1,427

Decommissioning Trust Fair Values

542

(b)

423

421

(c)

254

Decommissioning Liability

633

(b)

445

350

(c)

333

(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.

(b) ANO Units 1 and 2 are reported together.

(c) 30% of River Bend is not subject to rate regulation by the Public Utility Commission of Texas, the Louisiana Public Service Commission, nor various municipal authorities, and is included in non-utility property on the balance sheet. The decommissioning trust fund balance and decommissioning liability include amounts for the 30% not subject to rate regulation.

(d) Scope included installation of approximately 178 MW uprate; final uprated capacity amount to be determined after final testing and upon completion of NRC review.

50

UTILITY REGULATORY INFORMATION

STATE REGULATORY COMMISSIONS

	ARKANSAS	LOUISIANA	MISSISSIPPI	NEW ORLEANS	TEXAS
Commission	Arkansas Public	Louisiana	Mississippi	New Orleans	Public Utility
	Service	Public Service	Public Service	City Council	Commission
	Commission	Commission	Commission		of Texas
Number of Commissioners	3	5	3	7	3
Method of Selection	Appointed by	Elected	Elected	Elected	Appointed by
	Governor				Governor
Term of Office	6 years –	6 years –	4 years –	4 years –	6 years –
	staggered	staggered	concurrent	concurrent	staggered
				(2 term limit)
Chair / President	Appointed by	Selected by	Rotates every	Rotates annually	Appointed by
	Governor	peers – 1 year	1 - 2 years, as	from the	Governor
		term	determined by members	at-large positions

COMMISSION/COUNCIL MEMBERS

	PARTY	SERVICE BEGAN	CURRENT TERM ENDS
ARKANSAS
Colette Honorable – Chair	Democrat	10/07	1/17
Olan W. Reeves	unknown	1/09	1/15
Elana C. Wills	unknown	1/11	1/13
LOUISIANA
Foster L. Campbell, Jr. – Chairman	Democrat	1/03	12/14
James M. Field – Vice Chairman	Republican	12/96	12/12
Lambert C. Boissiere, III	Democrat	1/05	12/16
Eric Skrmetta	Republican	1/09	12/14
Clyde C. Holloway	Republican	4/09	12/16
MISSISSIPPI
Leonard Bentz – Chairman (2012)	Republican	4/06	12/15
Lynn Posey – Vice-Chairman (2012)	Republican	1/08	12/15
Brandon Presley	Democrat	1/08	12/15
NEW ORLEANS
Cynthia Hedge-Morrell – Chair of Utility Committee	Democrat	4/05	5/14
Jacquelyn Brechtel Clarkson – President of City Council	Democrat	11/07	5/14
Stacy S. Head – Vice-President of City Council	Democrat	5/06	5/14
Susan Guidry	Democrat	5/10	5/14
Jon Johnson	Democrat	5/10	5/14
Kristen Palmer	Democrat	5/10	5/14
Diana Bajoie(a)	Democrat	6/12	12/12
TEXAS
Donna L. Nelson – Chair	Republican	8/08	8/15
Kenneth W. Anderson Jr.	Republican	9/08	8/17
Rolando Pablos	Republican	9/11	9/13

(a) Interim appointment until November 2012 election.

51

SELECT UTILITY REGULATORY MECHANISMS

	LAST FILED	ALLOWED
	RATE BASE	ROE
COMPANY	($ billions)	(%)	JURISDICTIONAL REGULATORY MECHANISMS
EAI	4.0	10.2	Rate Case	•    No fixed schedule for rate filings. EAI filed its last rate case on September 4, 2009.
	6/30/09 with known and measurable changes through 6/30/10			•    In June 2010, the APSC approved a settlement in the EAI rate case. Key elements of the settlement include: an approximate $63.7 million base rate increase and a 10.2% allowed return on equity. New base rates became effective with the first billing cycle of July 2010. •    Next rate case filing expected to be tied to EAI’s exit from the System Agreement effective in December 2013.
EGSL	2.4 Electric	9.9 – 11.4 Electric	FRP	•    Annual filing in May; any change in rates typically effective in September.
	12/31/11	10.65 midpoint +/- 75 bps 60/40 customer/ company sharing		•    In October 2009, the LPSC approved an uncontested settlement extending the FRP regulatory process for an additional three years. The new FRP was adopted for the 2008-2010 test years and retains the 10.65% electric ROE midpoint with a +/- 75 bp bandwidth and a recovery mechanism for Commission-approved capacity additions. Earnings outside the bandwidth are allocated prospectively, 60% to customers and 40% to the company. In November 2011, the LPSC approved a one-year extension of EGSL’s FRP. EGSL is required to file a full rate case by January 2013.
	0.05 Gas 9/30/11	10.0 - 11.0 Gas 10.5 midpoint +/- 50 bps	RSP	•    In July 2005, the LPSC approved the EGSL Gas Rate Stabilization Plan (RSP) which specified a 10.5% gas ROE midpoint with a +/- 50 bp bandwidth. Outside the bandwidth, rate changes are determined as follows: +/- 200 bps, rates changed by 50% of difference necessary to bring earned return to end point of band; if more than +/- 200 bps, rates changed 100% to eliminate differential in excess of 200 bps and then same as if within +/- 200 bps.
ELL	3.6	9.45 – 11.05	FRP	•    Annual filing in May; any change in rates typically effective in September.
	12/31/2011	10.25 midpoint +/- 80 bps 60/40 customer/ company sharing		•    In October 2009, the LPSC approved an uncontested settlement extending the FRP regulatory process for an additional three years. The new FRP was adopted for the 2008-2010 test years and retains the 10.25% ROE midpoint with a +/- 80 bp bandwidth and a recovery mechanism for Commission-approved capacity additions. Earnings outside of the bandwidth are allocated prospectively, 60% to customers and 40% to the company. In November 2011, the LPSC approved a one-year extension of ELL’s FRP. ELL is required to file a full rate case by January 2013.
EMI	1.7 12/31/11	10.06 – 12.19 11.12 midpoint (subject to review / approval) Formulaic ROE reset Up to ~200 bps on ROE (depends on capital ratios) for price, satisfaction and reliability	FRP	•    Annual filing in March; any change in rates typically effective the first billing cycle of June. •    On March 4, 2010, the MPSC approved modifications to EMI’s FRP that (1) aligned EMI’s FRP more closely with the FRPs of the other regulated gas and electric utilities in Mississippi; (2) provided the opportunity to reset the ROE and bandwidth based upon performance ratings; (3) rescored the performance adjustment factors; (4) eliminated the $14.5 million revenue adjustment limit and changed the 2% of revenues limit to a 4% limit, with any adjustment over 2% requiring a hearing; and (5) directed EMI to phase-out the summer / winter rate differential in residential rates over two years. Returns inside the bandwidth result in no change in rates while returns outside the bandwidth reset rates prospectively to or within the bandwidth depending on performance.
ENOI	0.3 Electric 12/31/11 0.09 Gas 12/31/11	10.7 – 11.5 Electric 11.1 midpoint +/- 40 bps 10.25 – 11.25 Gas 10.75 midpoint +/- 50 bps Earnings outside bandwidth reset to midpoint ROE	FRP FRP	•    Annual filing in May; any change in rates typically effective in first billing cycle of October. •    On April 2, 2009, the City Council of New Orleans (CCNO) approved a comprehensive settlement. A new three-year formula rate plan was adopted, with terms including an 11.1% electric ROE midpoint with a +/- 40 bp bandwidth and a 10.75% gas ROE midpoint with a +/- 50 bp bandwidth. Earnings outside the bandwidth reset to the midpoint ROE, with rates changing on a prospective basis depending on whether ENOI is over or under-earning. The FRP also includes a recovery mechanism for Council-approved capacity additions, plus provisions for extraordinary cost changes and force majeure. The FRP may be extended by the mutual agreement of ENOI and the CCNO. The settlement also implemented energy conservation and demand programs. •    ENOI anticipates that it will discuss possible renewal or extension of the FRP with the CCNO Advisors during the course of the 2011 test year FRP proceeding, which was filed May 31, 2012. The CCNO would be required to approve any such renewal or extension.
ETI	1.7	10.125	Rate Case	•    No fixed schedule for rate filings.
	6/30/11 adjusted test year			•    ETI filed its last rate case on November 28, 2011 requesting a $111.8 million increase and a 10.6% return on equity based on an adjusted twelve-month test year ending June 30, 2011. In April 2012, ETI revised its request to a $104.8 million base rate increase. The parties have agreed to a procedural schedule that contemplates a final decision by July 30, 2012, with ultimate rates relating back to June 30, 2012. •    As a result of its December 30, 2009 rate case filing, ETI implemented a $17.5 million interim rate increase beginning on May 1, 2010, pursuant to a February 2010 unanimous settlement on interim rates and a $59 million base rate increase for usage on and after August 15, 2010, pursuant to its August 2010 stipulation and settlement agreement approved by the PUCT in December 2010. Other key elements of the stipulation and settlement agreement included an additional $9 million rate increase for bills rendered on and after May 2, 2011 (the first billing cycle of the month) and a 10.125% allowed return on equity.
SERI	1.0	10.94		•    Real-time recovery mechanism.
	monthly filing as of 5/31/12
TOTAL	14.7

52

UTILITY ELECTRIC AND GAS FUEL RECOVERY MECHANISMS

	DEFERRED FUEL BALANCE AS OF DECEMBER 31,
COMPANY	2011			2010			2009			2008			2007			FUEL RECOVERY MECHANISM
							($ millions)
EAI		209.8			61.5			122.8			119.1			114.8		Annual reset in April based on prior calendar year fuel and purchased power costs adjusted for nuclear refueling outages and projected sales plus any under- or over-recovered fuel balance for the prior calendar year.
EGSL(a)		2.9			77.8			57.8			8.1			105.8		Electric: Monthly reset based on fuel and purchased power costs from two months prior plus surcharge or credit for 1/12 of under- or over-recovered fuel balance.
																Gas: Monthly reset based on estimated gas costs plus a surcharge with an annual reset calculated by taking the over- or under- recovered balance at the end of June and dividing by the projected sales for the next 12 months.
ELL(a)		1.5			8.8			66.4			(23.6	)		19.2		Monthly reset based on fuel and purchased power costs from two months prior plus surcharge or credit for 1/12 of under- or over-recovered fuel balance.
EMI		(15.8	)		3.2			(72.9	)		5.0			(76.6	)	Quarterly reset based on projected fuel and purchased power costs and projected sales plus any under- or over-recovered fuel balance from the second prior quarter.
ENOI(b)		(7.5	)		(2.8	)		8.1			21.8			17.3		Electric: On April 2, 2009 the New Orleans City Council approved a new Fuel Adjustment Clause tariff that calculates a monthly rate based on fuel and purchased power costs from two months prior. A surcharge or credit will be calculated on any under- or over-recovered fuel balance based on the most recent 12 months actual kWh sales. Under the new tariff Grand Gulf non-fuel costs are recovered through base rates. Any incremental monthly Grand Gulf non-fuel costs are included in the Fuel Adjustment Clause. Resource Plan non-fuel costs are collected through the Fuel Adjustment Clause. The new tariff became effective on June 1, 2009.
																Gas: Monthly reset based on estimated gas costs plus a surcharge or credit for the under- or over-recovered fuel balance based on the most recent 12 months Mcf sales.
ETI		(64.7	)		(77.4	)		(102.7	)		21.2			(67.3	)	Semi-annual reset of fuel factor in March and September based on the market price of natural gas plus surcharge or refund for material under- or over-recoveries based on actual costs.
Total		126.2			71.1			79.5			151.6			113.2
Totals may not foot due to rounding.

(a) All years include $100.1 million for Entergy Gulf States Louisiana and $68 million for Entergy Louisiana of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be over a period greater than twelve months.

(b) 2011, 2010 and 2009 include $4.1 million for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be over a period greater than twelve months.

53

ENTERGY WHOLESALE COMMODITIES

EWC QUARTERLY FINANCIAL METRICS

	2011										2010
	1Q		2Q		3Q		4Q		YTD		1Q		2Q		3Q		4Q		YTD		% CHANGE
GAAP MEASURES
As-Reported Net Income ($ millions)		122.6		64.9		130.2		171.0		488.6		89.9		103.9		143.0		149.9		486.7		0
Return on Average Invested Capital – As-Reported (%)*		9.0		8.3		7.8		8.1		8.1		11.5		11.7		10.3		9.3		9.3		(13)
Return on Average Common Equity – As-Reported (%)*		9.5		8.7		8.0		8.4		8.4		11.8		12.1		10.4		9.4		9.4		(11)
Debt to Capital Ratio (%)		4.2		4.1		3.5		4.3		4.3		10.0		8.5		4.9		5.1		5.1		(16)
NON-GAAP MEASURES
Operational Adjusted EBITDA ($ millions)		253.4		174.3		241.0		193.5		862.2		290.9		229.3		246.6		280.7		1,047.5		(18)
Operational Earnings ($ millions)		122.6		64.9		130.2		171.0		488.6		144.2		118.4		168.2		156.6		587.4		(17)
Return on Average Invested Capital – Operational (%)*		9.8		8.9		7.9		8.1		8.1		13.2		13.4		12.2		11.1		11.1		(27)
Return on Average Common Equity – Operational (%)*		10.4		9.3		8.2		8.4		8.4		13.7		14.0		12.4		11.3		11.3		(26)
Net Debt to Net Capital Ratio (%)		(0.1)		(0.7)		(4.9)		(0.8)		(0.8)		(0.4)		3.0		(1.2)		(2.7)		(2.7)		(70)

*Rolling twelve months.

Totals may not foot due to rounding.

EWC ANNUAL FINANCIAL METRICS

	2011		2010		2009		2008		2007
GAAP MEASURES
As-Reported Net Income ($ millions)		488.6		486.7		638.5		795.6		583.2
Return on Average Invested Capital – As-Reported (%)		8.1		9.3		13.3		17.1		13.4
Return on Average Common Equity – As-Reported (%)		8.4		9.4		14.2		19.2		16.4
Debt to Capital Ratio (%)		4.3		5.1		10.5		13.0		18.3
NON-GAAP MEASURES
Operational Adjusted EBITDA ($ millions)		862.2		1,047.5		1,230.4		1,305.5		883.9
Operational Earnings ($ millions)		488.6		587.4		682.5		795.6		601.6
Return on Average Invested Capital – Operational (%)		8.1		11.1		14.1		17.1		13.7
Return on Average Common Equity – Operational (%)		8.4		11.3		15.1		19.2		17.0
Net Debt to Net Capital Ratio (%)		(0.8)		(2.7)		2.3		4.2		10.1

EWC QUARTERLY OPERATIONAL METRICS

	2011										2010										YTD
	1Q		2Q		3Q		4Q		YTD		1Q		2Q		3Q		4Q		YTD		% CHANGE
Owned Capacity (MW)(a)		6,016		6,016		6,016		6,599		6,599		6,351		6,351		6,351		6,351		6,351		4
Average Realized Revenue/MWh	$	56.98	$	52.32	$	55.87	$	52.74	$	54.48	$	58.31	$	58.15	$	61.51	$	58.16	$	59.04		(8)
Non-Fuel O&M Expense/Purchased Power per MWh(b)	$	24.95	$	26.87	$	25.32	$	25.37	$	25.62	$	23.90	$	26.93	$	29.59	$	26.74	$	26.76		(4	)
Billed GWh		10,519		10,652		11,284		11,065		43,520		11,128		10,498		10,736		10,320		42,682		2
EWC Nuclear
Average Realized Revenue/MWh	$	57.46	$	52.38	$	56.07	$	53.00	$	54.73	$	58.72	$	57.69	$	61.41	$	58.80	$	59.16		(7)
Production Cost/MWh(b)	$	24.01	$	25.96	$	24.92	$	25.92	$	25.21	$	23.70	$	24.40	$	27.79	$	25.23	$	25.27		(0	)
Non-Fuel O&M Expense/Purchased Power per MWh(b)	$	24.74	$	26.57	$	24.90	$	26.00	$	25.55	$	23.63	$	25.49	$	28.77	$	26.06	$	25.97		(2	)
Billed GWh		9,913		9,993		10,645		10,367		40,918		10,255		9,868		9,888		9,644		39,655		3
Capacity Factor		91%		91%		98%		93%		93%		94%		90%		91%		86%		90%		3

(a) Fourth quarter and year-to-date 2010 owned capacity includes the 335 MW ownership position in the Harrison County power plant, which was sold on December 31, 2010.

(b) 2010 and 2009 exclude the effects of the non-utility nuclear spin-off expenses special items at EWC Nuclear.

Totals may not foot due to rounding.

EWC ANNUAL OPERATIONAL METRICS

	2011		2010		2009		2008		2007
Owned Capacity (MW)(a)		6,599		6,351		6,351		6,351		6,576
Average Realized Revenue/MWh	$	54.48	$	59.04	$	60.46	$	60.73	$	53.69
Non-Fuel O&M Expense/Purchased Power per MWh(b)(c)	$	25.62	$	26.76	$	24.45	$	22.86	$	24.76
Billed GWh		43,520		42,682		43,969		44,747		40,916
EWC Nuclear
Net MW in Operation		4,998		4,998		4,998		4,998		4,998
Average Realized Price/MWh	$	54.73	$	59.16	$	61.07	$	59.51	$	52.69
Production Cost/MWh(b)(c)	$	25.21	$	25.27	$	23.26	$	21.88	$	21.19
Non-Fuel O&M Expense/Purchased Power per MWh(b)(c)	$	25.55	$	25.49	$	23.30	$	21.95	$	22.86
Billed GWh		40,918		39,655		40,981		41,710		37,570
Capacity Factor		93%		90%		93%		95%		89%

(a) Fourth quarter and year-to-date 2010 owned capacity includes the 335 MW ownership position in the Harrison County power plant, which was sold on December 31, 2010.

(b) 2010 and 2009 exclude the effects of the non-utility nuclear spin-off expenses special items at EWC Nuclear.

(c) 2007 excludes the effect of the non-utility nuclear alignment special item at EWC Nuclear.

Totals may not foot due to rounding.

TOTAL CAPACITY

	OPERATED						OWNED  CAPACITY(c)
As of June 2012.	PLANTS		UNITS		MW			MW		%
Gas/Oil		1		1		544(b)			1,340		20
Coal		-		-		- (b)			181		3
Total Fossil		1		1		544			1,521		23
Wind		-		-		-			80		1
Nuclear		6		7		5,811(a)			5,011(d)		76
Total Capacity		7		8		6,355			6,612		100

(a) Operated capacity includes management services contracts.

(b) Excludes units operated by Entergy’s utility companies.

(c) Includes capacity under power purchase agreements.

(d) Reflects the final testing and confirmation of a small incremental increase in output associated with equipment replacements installed at Palisades.

54

ENTERGY WHOLESALE COMMODITIES

EWC NUCLEAR PLANT STATISTICS

JAMES A.

INDIAN POINT

PALISADES

PILGRIM

VERMONT

FITZPATRICK

UNIT 2

UNIT 3

NUCLEAR PLANT

NUCLEAR STATION

YANKEE

Entergy Purchase Date

11/21/00

9/6/01

11/21/00

4/11/07

7/13/99

7/31/02

Commercial Operation Date

July 75

August 74

August 76

December 71

December 72

November 72

License Expiration Date

10/17/34

9/28/13

12/12/15

3/24/31

6/8/32

3/21/32

Architect/Engineer

Stone &

United

United

Combustion

Bechtel

Ebasco

Webster

Engineers &

Engineers &

Engineering

Power

Constructors

Constructors

Reactor Manufacturer

General

Westinghouse

Westinghouse

Combustion

General

General

Electric

Engineering

Electric

Electric

Reactor Type

BWR

PWR

PWR

PWR

BWR

BWR

Turbine Generator Manufacturer

General Electric

Westinghouse

Westinghouse

Westinghouse

General Electric

General Electric

Net MWs in Operation (MW)

838

1,028

1,041

811(e)

688

605

(as of December 31, 2011)

Refueling Data:

Last Date

9/12/10 –

3/5/12 –

3/9/11 –

4/8/12 –

4/18/11 –

10/8/11 –

10/17/10

4/1/12

4/8/11

4/30/12

5/12/11

11/2/11

Number of Days

35

28

30

23

25

25

Next Scheduled Refueling

Fall 12

Spring 14

Spring 13

Fall 13

Spring 13

Spring 13

2011 Capacity Factor

97%

98%

91%

94%

85%

92%

($ millions as of December 31, 2011)

Net Book Value

509

1,023

804

784

309

386(f)

Decommissioning Trust Fund Balance

(a)

693(b)

(a)

282

677

496

Decommissioning Liability

(a)

491(b)

(a)

306

362

332

Nearest Market Hub

NYISO

NYISO

NYISO

MISO

NEPOOL

NEPOOL

Zone A(c)

Zone G(d)

Zone G(d)

Cinergy

Mass Hub

Mass Hub

Capacity Zone (ICAP/UCAP)

NYISO

NYISO

NYISO

n/a

NEPOOL

NEPOOL

Rest of State

Rest of State

Rest of State

(a) NYPA retained the decommissioning trusts and decommissioning liability. NYPA and Entergy executed decommissioning agreements, specifying their decommissioning obligations. NYPA has the right to require Entergy to assume the decommissioning liability provided that it assigns the corresponding decommissioning trust, up to a specified level, to Entergy. If the decommissioning liability is retained by NYPA, Entergy will perform the decommissioning of the plants at a price equal to the lesser of a pre-specified level or the amount in the decommissioning trusts. Entergy believes that the amounts available to it under either scenario are sufficient to cover the future decommissioning costs without any additional contributions to the trusts.

(b) Includes amount for Indian Point 1. Indian Point 1 has been shut down and in safe storage since the 1970s.

(c) James A. FitzPatrick physically located in NYISO Zone C.

(d) Indian Point physically located in NYISO Zone H.

(e) Reflects the final testing and confirmation of a small incremental increase in output assoicated with equipment replacements.

(f) Under generally accepted accounting principles (GAAP), power plants and other long-lived assets are generally required to be accounted for on a historical cost basis, unless a triggering event occurs which requires an impairment evaluation. In the case of Vermont Yankee, as described in our prior financial statement filings with the U.S. Securities and Exchange Commission, Entergy has performed quarterly impairment evaluations since early 2010, triggered by state actions to shut down the plant early. A number of factors and inputs are used in the Vermont Yankee impairment evaluation, including the status of pending legal and state regulatory matters, as well as assumptions about future revenues and costs of the plant. Under the accounting rules, these inputs are required to be estimated as of the end of each quarterly period. The decline in the overall energy market and forward price of energy at March 31, 2012, which is used as an input in the current accounting analysis, yielded a different impairment result in the first quarter of 2012 as compared to earlier quarters, resulting in a pre-tax impairment charge of $(356) million of plant and related assets. As a result, net book value was $103 million as of March  31, 2012.

EWC NON-NUCLEAR WHOLESALE ASSETS PLANT STATISTICS

		NERC		COMMERCIAL		OWNERSHIP		NET		TOTAL		FUEL TYPE
PLANT	LOCATION	REGION		OPERATION		INTEREST		MW		MW		TECHNOLOGY
Independence – Unit 2	Newark, AR		SERC		1983		14%		121		842		Coal
Nelson 6	Westlake, LA		SERC		1982		11%		60		550		Coal
RS Cogen	Lake Charles, LA		SERC		2002		50%		213		425		CCGT Cogen
Ritchie – Unit 2	Helena, AR		SERC		1968		100%		544		544		Gas/Oil
Top of Iowa	Worth County, IA		MRO		2001		50%		40		80		Wind
White Deer	Amarillo, TX		SPP		2001		50%		40		80		Wind
Rhode Island State Energy Center (a)	Johnston, RI		NPCC		2002		100%		583		583		CCGT
Total									1,601		3,104

(a) Acquired December 21, 2011.

EWC NON-NUCLEAR WHOLESALE ASSETS PLANT EMISSIONS

					Emissions
	FUEL TYPE				SO2		NOx		CO2		Hg(a)
PLANT	TECHNOLOGY		PURPOSE		(tons)		(tons)		(tons)		(lbs)		TECHNOLOGY(b)
Independence – Unit 2		Coal		Base		2,173		921		849,764		32		OFA
Nelson 6		Coal		Base		1,584		399		488,817		18		LNB w Sep OFA
RS Cogen		CCGT Cogen		Base QF		4		377		805,403		0		Dry LNB / SCR
Ritchie – Unit 2		Gas/Oil		Peaking		-		-		-		-		-
Top of Iowa		Wind		Renewable		-		-		-		-		-
White Deer		Wind		Renewable		-		-		-		-		-
Rhode Island State Energy Center (c)		CCGT		Intermediate		7		66		1,291,509		0		Dry LNB / SCR
Total						3,768		1,763		3,435,493		50

(a) Mercury emissions calculated using 2011 unit heat input and 3.92 x 10-6 lb hg/MMBtu emissiom rate for coal plants and 8.0 x 10-10 lb hg/MMBtu emission rate for natural gas plants.

(b) Installed NOx and particulate matter emission control devices: Combustion Modification/ Fuel Reburning (Combus Mod / Fuel Reburn), Dry Low NOx Burners (Dry LNB), Electrostatic Precipitator (ESP), Low Nox Burners with Closed-coupled Overfire Air (LNB w/ Closed-coupled OFA), Low NOx Burners with Separated Overfire Air (LNB w/ Sep OFA), Low NOx Burner with Overfire Air (LNB w/ OFA), Overfire Air (OFA), Selective Catalytic Reduction (SCR) or Steam Injection. Currently have no SO₂, CO₂ or Mercury Control equipment operating on any unit.

(c) Acquired December 21, 2011.

Totals may not foot due to rounding.

55

ENTERGY WHOLESALE COMMODITIES

EWC NUCLEAR SECURITIES DETAIL

LONG-TERM DEBT:

NOTE TO NEW YORK POWER AUTHORITY (NYPA) RELATING TO THE PURCHASE OF FITZPATRICK AND INDIAN POINT 3

					ADDITIONAL LTD				TOTAL ENDING		TOTAL
			INTEREST		RELATED TO		INTEREST		LONG-TERM		INTEREST
($ thousands)	LONG-TERM DEBT(a)		EXPENSE		PURCHASE OF IP2		EXPENSE		DEBT		EXPENSE
2000		744,405		3,869		-		-		744,405		3,869
2001		682,512		35,392		74,402		1,190		756,914		36,582
2002		604,420		32,540		79,220		3,628		683,640		36,168
2003		441,845		27,387		72,863		3,643		514,708		31,030
2004		379,405		21,275		66,200		3,337		445,605		24,612
2005		313,968		18,277		59,218		3,018		373,186		21,295
2006		245,390		15,137		51,900		2,682		297,289		17,819
2007		173,445		11,845		44,231		2,331		217,676		14,176
2008		161,932		8,412		36,194		1,963		198,127		10,375
2009		149,771		7,839		27,772		1,577		177,543		9,416
2010		137,026		7,255		18,945		1,173		155,971		8,428
2011		123,669		6,643		9,694		750		133,363		7,393
2012		109,681		6,012		-		305		109,681		6,317
2013		95,011		5,331		-		-		95,011		5,331
2014		79,638		4,627		-		-		79,638		4,627
2015		61,027		3,889		-		-		61,027		3,889
2016		59,022		2,995		-		-		59,022		2,995
2017		56,921		2,899		-		-		56,921		2,899
2018		54,719		2,798		-		-		54,719		2,798
2019		52,412		2,693		-		-		52,412		2,693
2020		49,994		2,582		-		-		49,994		2,582
2021 – 2035 Average		-		1,400		-		-		-		1,400

(a) Includes plant, fuel, and license extension payments. Payments for plant and fuel are made annually on 11/21 (anniversary of close). As of 9/30/03, the entire fuel note has been paid off. Life extension payments made on anniversary of license expiration. Entergy will pay NYPA $2.5 million annually per plant, for up to twenty years if FitzPatrick and/or Indian Point 3 operate beyond their original license date.

Totals may not foot due to rounding.

EWC NON-NUCLEAR WHOLESALE ASSETS

EWC NON-NUCLEAR WHOLESALE ASSETS SECURITIES DETAIL

DEBT:

OUTSTANDING AS OF DECEMBER 31,

(ENTERGY’S SHARE)	2011	2010	2009	MATURITY	RATE
		(in millions)
RS Cogen Senior Project Debt
Bank Portion(a)	$40	$46	$51	10/17/18	LIBOR + 1.625%
Institutional Portion	$38	$38	$38	10/15/22	Fixed 8.73%
Debt Service Reserve Letter of Credit(b)	$  -	$  -	$  1	1 month to 6 months	LIBOR + 1.625%
RS Cogen Subordinated Debt	$13	$13	$13	10/17/17	LIBOR + 4.50%
Top Deer Senior Project Debt(c)	$  -	$  8	$13	06/30/13	Fixed 5.68%

(a) RS Cogen spread on bank portion increases over time from 1.375% to 2.375%.

(b) RS Cogen spread on Debt Service Reserve Letter of Credit Loan increases over time from 1.375% to 3.250%. The DSR LC fee was 1.375% in the first term and 1.625% in the second term, including 2009. The DSR LC is borrowed for interest periods of 1 month to 6 months as needed. The DSR LC was repaid on January 29, 2010.

(c) In December 2011, at the Company’s election and with the banks’ consent the outstanding balance on the credit facility was paid in full.

				SHARES OUTSTANDING
PREFERRED STOCK:				AS OF DECEMBER 31,						AS OF DECEMBER 31,
	RATE(a)			2011		2010		2009		2011		2010		2009
												(in millions)
Authorized 1,000,000 shares, $1 par value, cumulative
Without Sinking Fund:
Entergy Asset Management,		8.95	%		-		305,240		305,240	$	-	$	29.4	$	29.4
8.95% rate(a)
Other		-			-		-		-		-		0.9		1.5
Total without sinking fund					-		305,240		305,240	$	-	$	30.2	$	30.9

(a) Entergy Asset Management’s stockholders’ agreement provides that each December 31 either Entergy Asset Management or the preferred shareholders may request that the preferred dividend rate be reset.

Totals may not foot due to rounding.

56

DEFINITIONS OF OPERATIONAL MEASURES AND GAAP AND NON-GAAP FINANCIAL MEASURES

ENTERGY WHOLESALE COMMODITIES OPERATIONAL MEASURES

Owned capacity (MW)	Installed capacity owned and operated by Entergy Wholesale Commodities, including investments in wind generation accounted for under the equity method of accounting
Average realized revenue per MWh	As-reported revenue per MWh billed for Entergy Wholesale Commodities plants, excluding revenue from the amortization of the Palisades below-market PPA and investments in wind generation accounted for under the equity method of accounting
Non-fuel O&M expense/purchased power per MWh	Operation, maintenance and refueling expenses and purchased power per MWh billed, excluding fuel and investments in wind generation accounted for under the equity method of accounting
GWh billed	Total number of GWh billed to customers, excluding investments in wind generation accounted for under the equity method of accounting
NUCLEAR OPERATIONAL MEASURES
Net MW in operation	Installed capacity owned or operated by Entergy Wholesale Commodities - Nuclear
Average realized revenue per MWh	As-reported revenue per MWh billed for Entergy Wholesale Commodities nuclear plants, excluding revenue from the amortization of the Palisades below-market PPA
Production cost per MWh	Fuel and non-fuel operation and maintenance expenses according to accounting standards that directly relate to the production of electricity per MWh (based on net generation)
Non-fuel O&M expense/purchased power per MWh	Operation, maintenance and refueling expenses and purchased power per MWh billed, excluding fuel
GWh billed	Total number of GWh billed to all customers
Capability factor	The percentage of the maximum energy generation a plant is capable of supplying to the grid, limited only by factors within control of plant management; a high capability factor indicates effective plant programs and practices to minimize unplanned energy losses and to optimize planned outages
Capacity factor	Normalized percentage of the period that the nuclear plants generate power
Refueling outage duration	Number of days lost for scheduled refueling outage during the period

Financial measures defined in the below table include measures prepared in accordance with generally accepted accounting principles (GAAP), as well as non- GAAP measures. Non-GAAP measures are included in this report in order to provide metrics that remove the effect of less routine financial impacts from commonly used financial metrics.

FINANCIAL MEASURES – GAAP
Return on average invested capital – as-reported	12-months rolling net income attributable to Entergy Corporation (Net Income) adjusted to include preferred dividends and tax-effected interest expense divided by average invested capital
Return on average common equity – as-reported	12-months rolling Net Income divided by average common equity
Net margin – as-reported	12-months rolling Net Income divided by 12-months rolling revenue
Cash flow interest coverage	12-months cash flow from operating activities plus 12-months rolling interest paid, divided by interest expense
Book value per share	Common equity divided by end of period shares outstanding
Revolver capacity	Amount of undrawn capacity remaining on corporate and subsidiary revolvers
Total debt	Sum of short-term and long-term debt, notes payable, capital leases, and preferred stock with sinking fund on the balance sheet, less non-recourse debt, if any
Debt of joint ventures (Entergy’s share)	Debt issued by business joint ventures at Entergy Wholesale Commodities assets
Leases (Entergy’s share)	Operating leases held by subsidiaries capitalized at implicit interest rate
Debt to capital ratio	Gross debt divided by total capitalization
Securitization debt	Debt associated with securitization bonds issued to recover storm costs from hurricanes Rita, Ike and Gustav at Entergy Texas; the 2009 ice storm at Entergy Arkansas; and investment recovery of costs associated with the cancelled Little Gypsy repowering project at Entergy Louisiana
FINANCIAL MEASURES – NON-GAAP
Operational earnings	As-reported Net Income adjusted to exclude the impact of special items
Operational adjusted EBITDA	Earnings before interest, income taxes, depreciation and amortization, and interest and investment income excluding decommissioning expense, and other than temporary impairment losses on decommissioning trust fund assets, excluding effects of special items
Return on average invested capital – operational	12-months rolling operational Net Income adjusted to include preferred dividends and tax-effected interest expense divided by average invested capital
Return on average common equity – operational	12-months rolling operational Net Income divided by average common equity
Net margin – operational	12-months rolling operational Net Income divided by 12-months rolling revenue
Total gross liquidity	Sum of cash and revolver capacity
Debt to capital ratio, excluding securitization debt	Gross debt divided by total capitalization, excluding securitization debt
Net debt to net capital ratio, excluding securitization debt	Gross debt less cash and cash equivalents divided by total capitalization less cash and cash equivalents, excluding securitization debt
Net debt to net capital ratio, including off-balance sheet liabilities, excluding securitization debt	Sum of gross debt and off-balance sheet debt less cash and cash equivalents divided by sum of total capitalization and off-balance sheet debt less cash and cash equivalents, excluding securitization debt

57

REG G RECONCILIATIONS

PRO FORMA FINANCIAL RESULTS (Reflects Jurisdictional Split of Entergy Gulf States, Inc.) (unaudited)

RECONCILIATION OF GAAP TO NON-GAAP 2007 PRO FORMA INCOME STATEMENT In thousands, for the year ended December 31, 2007.	ENTERGY GULF STATES LOUISIANA GAAP			ADJUSTMENT*			ENTERGY GULF STATES LOUISIANA PRO FORMA
OPERATING REVENUES:
Electric		$3,448,008			$(1,238,442)			$2,209,566
Natural gas		86,604			-			86,604
Total		3,534,612			(1,238,442	)		2,296,170
OPERATING EXPENSES:
Operating and maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		867,081			(546,413	)		320,668
Purchased power		1,339,986			(232,938	)		1,107,048
Nuclear refueling outage expenses		12,212			-			12,212
Other operation and maintenance		548,999			(179,119	)		369,880
Decommissioning		11,728			(173	)		11,555
Taxes other than income taxes		132,489			(50,615	)		81,874
Depreciation and amortization		208,648			(68,172	)		140,476
Other regulatory charges (credits) – net		29,923			(16,808	)		13,115
Total		3,151,066			(1,094,238	)		2,056,828
OPERATING INCOME		383,546			(144,204	)		239,342
OTHER INCOME:
Allowance for equity funds used during construction		11,666			(3,295	)		8,371
Interest and dividend income		75,425			28,715			104,140
Miscellaneous – net		1,724			600			2,324
Total		88,815			26,020			114,835
INTEREST AND OTHER CHARGES:
Interest on long-term debt		149,464			(14,231	)		135,233
Other interest – net		13,945			(10,907	)		3,038
Allowance for borrowed funds used during construction		(7,528	)		2,126			(5,402	)
Total		155,881			(23,012	)		132,869
INCOME BEFORE INCOME TAXES		316,480			(95,172	)		221,308
Income taxes		134,098			(36,249	)		97,849
NET INCOME		182,382			(58,923	)		123,459
Preferred distribution requirements and other		3,968			-			3,968
EARNINGS APPLICABLE TO COMMON EQUITY		$   178,414			$    (58,923)			$   119,491

*Adjustment to reflect as if the transactions implementing the Entergy Gulf States, Inc. jurisdictional split had occurred as of January 1, 2007.

58

REG G RECONCILIATIONS

CONSOLIDATED FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES

2007-2011

($ millions)	2011			2010			2009			2008			2007
As-Reported Net Income (A)		1,346			1,250			1,231			1,221			1,135
Preferred dividends		21			20			20			20			25
Tax-effected interest expense		316			354			351			374			392
As-Reported Net Income including preferred dividends and tax-effected interest expense (B)		1,683			1,624			1,602			1,615			1,552
Special items (C)		(13	)		(82	)		(71	)		(55	)		(32	)
Operational earnings including preferred dividends and tax-effected interest expense (B-C)		1,696			1,706			1,673			1,670			1,584
Operational earnings (A-C)		1,359			1,332			1,302			1,276			1,167
Average invested capital (D)		21,126			20,781			20,748			19,927			18,721
Average common equity (E)		8,729			8,555			8,290			7,915			8,030
Operating revenues (F)		11,229			11,488			10,746			13,094			11,484
Gross debt (G)		12,387			11,816			12,014			12,279			11,123
Less securitization debt (H)		1,071			931			838			310			330
Gross debt, excluding securitization debt (G-H)		11,316			10,885			11,176			11,969			10,793
Less cash and cash equivalents (I)		694			1,294			1,710			1,920			1,254
Net debt, excluding securitization debt (G-H-I)		10,622			9,591			9,466			10,049			9,539
Total capitalization (J)		21,629			20,623			20,939			20,557			19,297
Less securitization debt (K)		1,071			931			838			310			330
Total capitalization, excluding securitization debt (J-K)		20,558			19,692			20,101			20,247			18,967
Less cash and cash equivalents (L)		694			1,294			1,710			1,920			1,254
Net capitalization, excluding securitization debt (J-K-L)		19,864			18,398			18,391			18,327			17,713
Off-balance sheet liabilities (M)		604			653			646			574			658
Revolver capacity (N)		2,001			2,354			1,464			645			1,730
Gross liquidity (I+N)		2,695			3,648			3,174			2,565			2,984
($ per share)
As-Reported earnings per share (O)		7.55			6.66			6.30			6.20			5.60
Operational earnings per share (P)		7.62			7.10			6.67			6.51			5.76
Common dividend paid per share (Q)		3.32			3.24			3.00			3.00			2.58
Year-end closing market price per share of common stock (R)		73.05			70.83			81.84			83.13			119.52
(%)
Return on average invested capital – As-Reported (B/D)		8.0			7.8			7.7			8.1			8.3
Return on average invested capital – Operational ((B-C)/D)		8.0			8.2			8.1			8.4			8.5
Return on average common equity – As-Reported (A/E)		15.4			14.6			14.9			15.4			14.1
Return on average common equity – Operational ((A-C)/E)		15.6			15.6			15.7			16.1			14.5
Net margin – As-Reported (A/F)		12.0			10.9			11.5			9.3			9.9
Net margin – Operational ((A-C)/F)		12.1			11.6			12.1			9.7			10.2
Debt to capital ratio (G/J)		57.3			57.3			57.4			59.7			57.6
Debt to capital ratio, excluding securitization debt ((G-H)/(J-K))		55.0			55.3			55.6			59.1			56.9
Net debt to net capital ratio, excluding securitization debt ((G-H-I)/(J-K-L))		53.5			52.1			51.5			54.8			53.9
Net debt to net capital ratio including off-balance sheet liabilities, excluding securitization debt ((G-H-I+M)/(J-K-L+M))		54.8			53.8			53.1			56.2			55.5
Common dividend payout ratio – As-Reported (Q/O)		44			49			48			48			46
Common dividend payout ratio – Operational (Q/P)		44			46			45			46			45
(ratio)
Price to earnings ratio – As-Reported (R/O)		9.68			10.64			12.99			13.41			21.34
Price to earnings ratio – Operational (R/P)		9.59			9.98			12.27			12.77			20.75

Calculations may differ due to rounding.

59

REG G RECONCILIATIONS

CONSOLIDATED FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES

1Q10-4Q11

($ millions)	1Q11			2Q11			3Q11			4Q11			1Q10			2Q10			3Q10			4Q10
For the quarter:
As-Reported Net Income (A)		248.7			315.6			628.1			154.1			213.8			315.3			492.9			228.3
Less special items (B)		-			-			-			(13.0	)		(39.9	)		(10.5	)		(25.2	)		(6.7	)
Operational earnings (A-B)		248.7			315.6			628.1			167.2			253.7			325.7			518.1			235.0
As-Reported Net Income rolling 12 months (C)		1,285			1,285			1,421			1,346			1,210			1,298			1,336			1,250
Preferred dividends		20			20			20			21			20			20			20			20
Tax-effected interest expense		327			320			320			316			372			368			358			354
As-Reported Net Income, rolling 12 months including preferred dividends and tax-effected interest expense (D)		1,632			1,625			1,761			1,683			1,602			1,686			1,714			1,624
Special items in prior quarters		(42	)		(32	)		(7	)		-			(53	)		(76	)		(71	)		(75	)
Special items in current quarter
Parent & Other
Transmission business spin-merge expenses		-			-			-			(13	)		-			-			-			-
Non-utility nuclear spin-off expenses		-			-			-			-			14			4			-			-
Entergy Wholesale Commodities
Non-utility nuclear spin-off expenses		-			-			-			-			(54	)		(15	)		(25	)		(7	)
Total special items (E)		(42	)		(32	)		(7	)		(13	)		(94	)		(87	)		(96	)		(82	)
Operational earnings, rolling 12 months including preferred dividends and tax-effected interest expense (D-E)		1,674			1,657			1,768			1,696			1,696			1,773			1,810			1,706
Operational earnings, rolling 12 months (C-E)		1,327			1,317			1,428			1,359			1,304			1,385			1,432			1,332
Average invested capital (F)		21,093			21,101			21,509			21,126			21,149			20,761			20,802			20,781
Average common equity (G)		8,698			8,684			8,849			8,729			8,745			8,769			8,608			8,555
Operating revenues, rolling 12 months (H)		11,269			11,210			11,273			11,229			10,716			11,058			11,453			11,488
Gross debt (I)		12,018			12,360			12,452			12,387			12,152			11,853			12,247			11,816
Less securitization debt (J)		910			896			1,086			1,071			838			829			940			931
Gross debt, excluding securitization debt (I-J)		11,108			11,464			11,366			11,316			11,314			11,024			11,307			10,885
Less cash and cash equivalents (K)		726			530			987			694			1,657			1,336			1,931			1,294
Net debt, excluding securitization debt (I-J-K)		10,382			10,934			10,379			10,622			9,657			9,688			9,376			9,591
Total capitalization (L)		20,864			21,268			21,728			21,629			21,322			20,935			21,290			20,623
Less securitization debt (M)		910			896			1,086			1,071			838			829			940			931
Total capitalization, excluding securitization debt (L-M)		19,954			20,372			20,642			20,558			20,484			20,106			20,350			19,692
Less cash and cash equivalents (N)		726			530			987			694			1,657			1,336			1,931			1,294
Net capitalization, excluding securitization debt (L-M-N)		19,228			19,842			19,655			19,864			18,827			18,770			18,419			18,398
Off-balance sheet liabilities (O)		650			647			645			604			644			641			638			653
Revolver capacity (P)		2,258			1,993			2,116			2,001			1,417			1,338			2,216			2,354
Gross liquidity (K+P)		2,984			2,523			3,103			2,695			3,074			2,674			4,147			3,648
(%)
Return on average invested capital – As-Reported (D/F)		7.7			7.7			8.2			8.0			7.6			8.1			8.2			7.8
Return on average invested capital – Operational ((D-E)/F)		7.9			7.9			8.2			8.0			8.0			8.5			8.7			8.2
Return on average common equity – As-Reported (C/G)		14.8			14.8			16.1			15.4			13.8			14.8			15.5			14.6
Return on average common equity – Operational ((C-E)/G)		15.3			15.2			16.1			15.6			14.9			15.8			16.6			15.6
Net margin – As-Reported (C/H)		11.4			11.5			12.6			12.0			11.3			11.7			11.7			10.9
Net margin – Operational ((C-E)/H)		11.8			11.8			12.7			12.1			12.2			12.5			12.5			11.6
Debt to capital ratio (I/L)		57.6			58.1			57.3			57.3			57.0			56.6			57.5			57.3
Debt to capital ratio, excluding securitization debt ((I-J)/(L-M))		55.7			56.3			55.1			55.0			55.2			54.8			55.6			55.3
Net debt to net capital ratio, excluding securitization debt ((I-J-K)/(L-M-N))		54.0			55.1			52.8			53.5			51.3			51.6			50.9			52.1
Net debt to net capital including off-balance sheet liabilities, excluding securitization debt ((I-J-K+O)/(L-M-N+O))		55.5			56.5			54.3			54.8			52.9			53.2			52.5			53.8

Calculations may differ due to rounding.

60

REG G RECONCILIATIONS

UTILITY FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES

2007-2011

($ millions)	2011	2010	2009	2008	2007
As-Reported Net Income (A)	1,106.5	812.4	691.6	587.8	682.7
Preferred dividends	17.3	17.3	17.3	17.3	21.7
Tax-effected interest expense	280.4	303.4	284.3	261.6	259.8
As-Reported Net Income including preferred dividends and tax-effected interest expense (B)	1,404.2	1,133.2	993.3	866.7	964.2
Utility special items
Nuclear alignment	-	-	-	-	(13.7	)
Total special items (C)	-	-	-	-	(13.7	)
Operational earnings including preferred dividends and tax-effected interest expense (B-C)	1,404.2	1,133.2	993.3	866.7	977.9
Operational earnings (A-C)	1,106.5	812.4	691.6	587.8	696.4
Average invested capital (D)	16,877	16,412	15,580	14,441	13,903
Average common equity (E)	7,462	7,109	6,828	6,618	6,440
Gross debt (F)	9,332	8,937	9,107	7,836	7,249
Less securitization debt (G)	1,071	931	838	310	330
Gross debt, excluding securitization debt (F-G)	8,262	8,006	8,269	7,526	6,919
Less cash and cash equivalents (H)	360	822	1,239	566	801
Net debt, excluding securitization debt (F-G-H)	7,902	7,185	7,030	6,960	6,118
Total capitalization (I)	17,298	16,457	16,367	14,794	14,088
Less securitization debt (J)	1,071	931	838	310	330
Total capitalization, excluding securitization debt (I-J)	16,227	15,526	15,529	14,484	13,758
Less cash and cash equivalents (K)	360	822	1,239	566	801
Net capitalization, excluding securitization debt (I-J-K)	15,867	14,704	14,290	13,918	12,957
(%)
Return on average invested capital – As-Reported (B/D)	8.3	6.9	6.4	6.0	6.9
Return on average invested capital – Operational ((B-C)/D)	8.3	6.9	6.4	6.0	7.0
Return on average common equity – As-Reported (A/E)	14.8	11.4	10.1	8.9	10.6
Return on average common equity – Operational ((A-C)/E)	14.8	11.4	10.1	8.9	10.8
Debt to capital ratio (F/I)	54.0	54.3	55.6	53.0	51.5
Debt to capital ratio, excluding securitization debt ((F-G)/(I-J))	50.9	51.6	53.2	52.0	50.3
Net debt to net capital ratio, excluding securitization debt ((F-G-H)/(I-J-K))	49.8	48.9	49.2	50.0	47.2

Calculations may differ due to rounding.

61

REG G RECONCILIATIONS

UTILITY FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES

1Q10-4Q11

($ millions)	1Q11	2Q11	3Q11	4Q11	1Q10	2Q10	3Q10	4Q10
As-Reported Net Income (A)	164.3	248.4	524.1	169.7	138.6	225.8	333.6	114.3
Less special items (B)	-	-	-	-	-	-	-	-
Operational earnings (A-B)	164.3	248.4	524.1	169.7	138.6	225.8	333.6	114.3
As-Reported Net Income-rolling 12 months (C)	838.1	860.6	1,051.2	1,106.5	718.6	797.2	836.0	812.4
Preferred dividends	17.3	17.3	17.3	17.3	17.3	17.3	17.3	17.3
Tax-effected interest expense	298.0	287.2	283.3	280.4	294.2	304.0	303.6	303.4
As-Reported Net Income, rolling 12 months including preferred dividends and tax-effected interest expense (D)	1,153.4	1,165.1	1,351.8	1,404.2	1,030.1	1,118.5	1,157.0	1,133.2
Special items in prior quarters	-	-	-	-	-	-	-	-
Special items in current quarter	-	-	-	-	-	-	-	-
Total special items (E)	-	-	-	-	-	-	-	-
Operational earnings, rolling 12 months including preferred dividends and tax-effected interest expense (D-E)	1,153.4	1,165.1	1,351.8	1,404.2	1,030.1	1,118.5	1,157.0	1,133.2
Operational earnings, rolling 12 months (C-E)	838.1	860.6	1,051.2	1,106.5	718.6	797.2	836.0	812.4
Average invested capital (F)	16,583	16,682	16,923	16,877	15,730	15,858	16,040	16,412
Average common equity (G)	7,139	7,257	7,391	7,462	6,880	6,977	7,080	7,109
Gross debt (H)	9,131	9,305	9,432	9,332	9,197	8,984	9,071	8,937
Less securitization debt (I)	911	896	1,086	1,071	838	829	940	931
Gross debt, excluding securitization debt (H-I)	8,221	8,409	8,346	8,262	8,358	8,155	8,131	8,006
Less cash and cash equivalents (J)	439	226	467	360	1,039	990	1,055	822
Net debt, excluding securitization debt (H-I-J)	7,782	8,183	7,879	7,902	7,320	7,166	7,075	7,185
Total capitalization (K)	16,686	17,003	17,364	17,298	16,481	16,360	16,481	16,457
Less securitization debt (L)	911	896	1,086	1,071	838	829	940	931
Total capitalization, excluding securitization debt (K-L)	15,776	16,108	16,278	16,227	15,642	15,531	15,541	15,526
Less cash and cash equivalents (M)	439	226	467	360	1,039	990	1,055	822
Net capitalization, excluding securitization debt (K-L-M) (%)	15,337	15,882	15,811	15,867	14,603	14,542	14,486	14,704
Return on average invested capital –
As-Reported (D/F)	7.0	7.0	8.0	8.3	6.5	7.1	7.2	6.9
Return on average invested capital –
Operational ((D-E)/F)	7.0	7.0	8.0	8.3	6.5	7.1	7.2	6.9
Return on average common equity –
As-Reported (C/G)	11.7	11.9	14.2	14.8	10.4	11.4	11.8	11.4
Return on average common equity –
Operational ((C-E)/G)	11.7	11.9	14.2	14.8	10.4	11.4	11.8	11.4
Debt to capital ratio (H/K)	54.7	54.7	54.3	54.0	55.8	54.9	55.0	54.3
Debt to capital ratio, excluding securitization debt ((H-I)/(K-L))	52.1	52.2	51.3	50.9	53.4	52.5	52.3	51.6
Net debt to net capital ratio, excluding securitization debt ((H-I-J)/(K-L-M))	50.7	51.5	49.8	49.8	50.1	49.3	48.8	48.9

Calculations may differ due to rounding.

62

REG G RECONCILIATIONS

ENTERGY ARKANSAS FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES

2007-2011

($ millions)	2011		2010		2009		2008		2007
As-Reported Earnings (A)		158.0		165.7		60.0		40.3		132.2
Preferred dividends		6.9		6.9		6.9		6.9		6.9
Tax-effected interest expense		49.7		54.9		54.9		52.0		53.4
As-Reported Earnings including preferred dividends and tax-effected interest expense (B)		214.6		227.6		121.8		99.2		192.5
Special items
Nuclear Alignment		-		-		-		-		(5.9	)
Total special items (C)		-		-		-		-		(5.9	)
Operational earnings including preferred dividends and tax-effected interest expense (B-C)		214.6		227.6		121.8		99.2		198.4
Operational earnings (A-C)		158.0		165.7		60.0		40.3		138.1
Average invested capital (D)		3,460		3,385		3,291		3,102		2,965
Average invested capital, excluding securitization (E)		3,341		3,323		3,291		3,102		2,965
Average common equity (F)		1,424		1,408		1,406		1,392		1,409
Gross debt (G)		1,911		1,928		1,793		1,745		1,442
Less securitization debt (H)		114		124		-		-		-
Gross debt, excluding securitization debt (G-H)		1,797		1,804		1,793		1,745		1,442
Less cash and cash equivalents (I)		23		106		86		40		0.2
Net debt, excluding securitization debt (G-H-I)		1,775		1,698		1,707		1,705		1,441
Total capitalization (J)		3,472		3,448		3,321		3,261		2,942
Less securitization debt (K)		114		124		-		-		-
Total capitalization, excluding securitization debt (J-K)		3,358		3,324		3,321		3,261		2,942
Less cash and cash equivalents (L)		23		106		86		40		0.2
Net capitalization, excluding securitization debt (J-K-L)		3,335		3,218		3,235		3,221		2,942
(%)
Return on average invested capital – As-Reported (B/D)		6.2		6.7		3.7		3.2		6.5
Return on average invested capital – Operational ((B-C)/E)		6.4		6.8		3.7		3.2		6.7
Return on average common equity – As-Reported (A/F)		11.1		11.8		4.3		2.9		9.4
Return on average common equity – Operational ((A-C)/F)		11.1		11.8		4.3		2.9		9.8
Debt to capital ratio (G/J)		55.0		55.9		54.0		53.5		49.0
Debt to capital ratio, excluding securitization debt ((G-H)/(J-K))		53.5		54.3		54.0		53.5		49.0
Net debt to net capital ratio, excluding securitization debt ((G-H-I)/(J-K-L))		53.2		52.8		52.8		52.9		49.0

Calculations may differ due to rounding.

63

REG G RECONCILIATIONS

ENTERGY GULF STATES LOUISIANA FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES

2007-2011

($ millions)	2011		2010		2009		2008		2007
As-Reported Earnings (A)		200.8		173.5		152.5		131.1		119.5
Preferred dividends		0.8		0.8		0.8		0.8		4.0(a)
Tax-effected interest expense		49.7		60.2		70.7		78.1		81.8(a)
As-Reported Earnings including preferred dividends and tax-effected interest expense (B)		251.3		234.6		224.0		210.0		205.3
Special items
Nuclear Alignment		-		-		-		-		(3.6	)
Total special items (C)		-		-		-		-		(3.6	)
Operational earnings including preferred dividends and tax-effected interest expense (B-C)		251.3		234.6		224.0		210.0		208.9
Operational earnings (A-C)		200.8		173.5		152.5		131.1		123.1
Average invested capital (D)		2,962		3,122		3,344		3,618		3,175
Average invested capital, excluding assumption debt (E)		2,962		3,039		2,875		2,693		2,636
Average common equity (F)		1,389		1,429		1,348		1,284		1,243(b)
Gross debt (G)		1,542		1,584		1,783		2,188		2,460
Less assumption debt (H)		-		-		168		770		1,079
Gross debt, excluding assumption debt (G-H)		1,542		1,584		1,615		1,418		1,381
Less cash and cash equivalents (I)		25		155		144		49		108
Net debt, excluding assumption debt (G-H-I)		1,517		1,429		1,471		1,369		1,273
Total capitalization (J)		2,876		3,049		3,196		3,491		3,744
Less assumption debt (K)		-		-		168		770		1,079
Total capitalization, excluding assumption debt (J-K)		2,876		3,049		3,028		2,721		2,665
Less cash and cash equivalents (L)		25		155		144		49		108
Net capitalization, excluding assumption debt (J-K-L)		2,851		2,893		2,884		2,672		2,557
(%)
Return on average invested capital – As-Reported (B/D)		8.5		7.5		6.7		5.8		6.5
Return on average invested capital – Operational ((B-C)/E)		8.5		7.7		7.8		7.8		7.9
Return on average common equity – As-Reported (A/F)		14.5		12.1		11.3		10.2		9.6
Return on average common equity – Operational ((A-C)/F)		14.5		12.1		11.3		10.2		9.9
Debt to capital ratio (G/J)		53.6		52.0		55.8		62.7		65.7
Debt to capital ratio, excluding assumption debt ((G-H)/(J-K))		53.6		52.0		53.3		52.1		51.8
Net debt to net capital ratio, excluding assumption debt ((G-H-I)/(J-K-L))		53.2		49.4		51.0		51.2		49.8

ENTERGY TEXAS – RECONCILIATION OF GAAP TO NON-GAAP MEASURES

2007-2011

($ millions)	2011		2010		2009		2008		2007
As-Reported Net Income (A)		80.8		66.2		63.8		57.9		58.9
Preferred dividends		-		-		-		-		-
Tax-effected interest expense		56.0		56.5		63.9		48.0		51.2
As-Reported Net Income including preferred dividends and tax-effected interest expense (B)		136.8		122.7		127.7		105.9		110.1
Special items		-		-		-		-		-
Total special items (C)		-		-		-		-		-
Operational earnings including preferred dividends and tax-effected interest expense (B-C)		136.8		122.7		127.7		105.9		110.1
Operational earnings (A-C)		80.8		66.2		63.8		57.9		58.9
Average invested capital (D)		2,530		2,493		2,374		2,331		2,245
Average invested capital, excluding securitization and equity infusion from parent (E)		1,752		1,670		1,799		1,936		1,931
Average common equity (F)		862		834		872		952		996
Average common equity, excluding equity infusion from parent returned beginning of 08 (G)		862		834		872		877		846
Gross debt (H)		1,677		1,659		1,658		1,345		1,413
Less securitization debt (I)		750		807		838		310		330
Gross debt, excluding securitization debt (H-I)		927		852		820		1,035		1,083
Less cash and cash equivalents (J)		65		35		201		2		297
Net debt, excluding securitization debt (H-I-J)		862		817		619		1,033		786
Total capitalization (K)		2,576		2,484		2,503		2,245		2,417
Less securitization debt (L)		750		807		838		310		330
Less equity infusion from parent returned beginning of 08 (M)		-		-		-		-		150
Total capitalization, excluding securitization and equity infusion from parent (K-L-M)		1,827		1,676		1,664		1,935		1,937
Less cash and cash equivalents (N)		65		35		201		2		297
Net capitalization, excluding securitization and equity infusion from parent (K-L-M-N)		1,762		1,641		1,463		1,933		1,640
(%)
Return on average invested capital – As-Reported (B/D)		5.4		4.9		5.4		4.5		4.9
Return on average invested capital – Operational ((B-C)/E)		7.8		7.3		7.1		5.5		5.7
Return on average common equity – As-Reported (A/F)		9.4		7.9		7.3		6.1		5.9
Return on average common equity – Operational ((A-C)/G)		9.4		7.9		7.3		6.6		7.0
Debt to capital ratio (H/K)		65.1		66.8		66.3		59.9		58.5
Debt to capital ratio, excluding securitization and equity infusion from parent ((H-I)/(K-L-M))		50.8		50.8		49.3		53.5		55.9
Net debt to net capital ratio, excluding securitization and equity infusion from parent ((H-I-J)/(K-L-M-N))		48.9		49.8		42.3		53.4		47.9

(a) See page 58 for the Pro Forma EGSL Income Statement.

(b) See page 65 for the Pro Forma EGSL Average Common Equity.

Calculations may differ due to rounding.

64

REG G RECONCILIATIONS

ENTERGY GULF STATES AND ENTERGY TEXAS FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES

EGSL PRO FORMA AVERAGE COMMON EQUITY 2007 ($ millions)	(D) EGSI 2006 PER 10-K			(E) ADJUSTMENTS			(D-E) EGSL 2006 PRO FORMA
Shareholders Equity:
Preferred membership interests without sinking fund (A)		47			(1	)		48
Members’ equity		2,220			988			1,233
Accumulated other comprehensive loss		(20	)		-			(20	)
Total Equity (B)		2,248			987			1,261
2006 Pro Forma Total Common Equity (B–A)								1,213
2007 Total Common Equity (C)								1,274
2007 Average Common Equity ((C)+(B–A))/2								1,243

EGSL / ETI AVERAGE INVESTED CAPITAL AND RETURN ON AVERAGE INVESTED CAPITAL	2007 PRO FORMA
($ millions)	ETI		EGSL
As-Reported Net Income (A)		58.9		119.5	(a)
Preferred dividends		-		4.0	(a)
Tax-effected interest expense		51.2		81.8	(a)
As-Reported Net Income including preferred dividends and tax-effected interest expense (B)		110.1		205.3
Total Special Items (C)		-		(3.6	)
Operational earnings including preferred dividends and tax-effected interest expense (B-C)		110.1		208.9
Average Invested Capital (D)		2,245		3,175
Less Average Securitization Debt (E)		165		-
Less Average Equity Infusion from Parent (F)		150		-
Less Average Assumption Debt (G)		-		540
Adjusted Average Invested Capital (D-E-F-G)		1,931		2,636
ROIC – As-Reported (B/D)		4.9%		6.5%
ROIC – Operational ((B-C)/(D-E-F-G)		5.7%		7.9%

ETI AVERAGE COMMON EQUITY AND RETURN ON AVERAGE COMMON EQUITY
($ millions)	2008			2007 PRO FORMA
As-Reported Net Income (A)		57.9			58.9
Total Special Items (B)		-			-
Operational Earnings (A–B)		57.9			58.9
Average Common Equity (C)		952.2			996.1
Less Average Equity Infusion from Parent		75.0			150.0
Adjusted Average Common Equity (D)		877.2			846.1
ROE – As-Reported (A/C)		6.1	%		5.9%
ROE – Operational ((A–B)/D)		6.6	%		7.0%

EGSL / ETI DEBT TO CAPITAL RATIO	2007 PRO FORMA
($ millions)	ETI		EGSL
Currently maturing long-term debt		309		675
Notes Payable		-		-
Obligations under capital leases – current		-		29
Obligations under capital leases – non-current		-		82
Long-term debt		1,104		1,674
Total debt before adjustments (A)		1,413		2,460
Less debt assumption by ETI (EGSL) (B)		-		1,079
Less securitization debt (ETI) (C)		330		-
Adjusted total debt (A-B-C)		1,083		1,381
Shareholders’ equity (D)		1,004		1,274
Less return of parent equity infusion in beginning of 08		150		-
Adjusted Common Equity (E)		854		1,274
Preferred membership interests without sinking fund (F)		-		10
Adjusted total capital (A-B-C)+(E+F)		1,937		2,665
Adjusted Debt / Capital Ratio (A-B-C)/((A-B-C)+(E+F))		55.9%		51.8%

EGSL / ETI NET DEBT TO NET CAPITAL RATIO	2007 PRO FORMA
($ millions)	ETI		EGSL
Currently maturing long-term debt		309		675
Notes Payable		-		-
Obligations under capital leases – current		-		29
Obligations under capital leases – non-current		-		82
Long-term debt		1,104		1,674
Total debt before adjustments (A)		1,413		2,460
Less debt assumption by ETI (EGSL) (B)		-		1,079
Less securitization debt (ETI) (C)		330		-
Adjusted total debt (A-B-C)		1,083		1,381
Less cash and cash equivalents (D)		297		108
Net Debt (A-B-C-D)		786		1,273
Shareholders’ equity (E)		1,004		1,274
Less return of parent equity infusion in beginning of 08		150		-
Adjusted Common Equity (F)		854		1,274
Preferred membership interests without sinking fund (G)		-		10
Adjusted total capital (A-B-C)+(F+G)		1,937		2,665
Less cash and cash equivalents (D)		297		108
Net Capitalization (A-B-C)+(F+G)-(D)		1,640		2,557
Adjusted Net Debt / Net Capital Ratio (A-B-C-D)/((A-B-C)+(F+G)-(D))		47.9%		49.8%

(a) See page 58 for the Pro Forma EGSL Income Statement.

Calculations may differ due to rounding.

65

REG G RECONCILIATIONS

ENTERGY GULF STATES AND ENTERGY TEXAS FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES (continued)

EGSL PRO FORMA CASH FLOW INTEREST COVERAGE

2007

	(A)			(B)			(A-B)
	EGSL(a)			ETI			EGSL
($ thousands)	PER 2007 10-K			PER FORM 10			PRO FORMA
Net Income		182,382			58,921			123,461
Adjustments to reconcile net income to net cash flow provided by operating activities:
Reserve for regulatory adjustments		363			(363	)		726
Other regulatory charges (credits) – net		29,923			16,808			13,115
Depreciation, amortization, and decommissioning		220,376			68,345			152,031
Deferred income taxes, investment tax credits, and non-current taxes accrued		109,131			218,873			(109,742	)
Changes in working capital:
Receivables		(261,538	)		(230,481	)		(31,057	)
Fuel inventory		(18,377	)		(10,939	)		(7,438	)
Accounts payable		38,685			(1,328	)		40,013
Taxes accrued		(27,781	)		4,936			(32,717	)
Interest accrued		22,963			10,030			12,933
Deferred fuel costs		35,363			21,619			13,744
Other working capital accounts		197,802			86,598			111,204
Provision for estimated losses and reserves		(91,241	)		(568	)		(90,673	)
Changes in other regulatory assets		116,317			(21,038	)		137,355
Other		6,372			(45,422	)		51,794
Net Cash Flow from Operating Activities		560,740			175,991			384,749
EGSL Pro Forma Net Cash Flow from Operating Activities					(C	)		384,749
Cash Paid During Period for Interest – net of amount capitalized					(D	)		131,280
Operating Cash Flow before Interest Payments					(C+D	)		516,029
Interest and Other Charges					(E	)		132,869	(a)
Pro Forma Cash Flow Interest Coverage					((C+D)/E)			3.9

(a) Entergy Gulf States Louisiana, L.L.C. (EGSL) is the successor for financial reporting purposes to Entergy Gulf States, Inc. EGSL’s Cash Flow Statement for the year ended 2007 includes the operations of Entergy Texas, Inc.

ENTERGY LOUISIANA FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES

2007-2011

($ millions)	2011		2010		2009		2008		2007
As-Reported Earnings (A)		467.0		224.5		225.9		150.6		136.4
Preferred dividends		7.0		7.0		7.0		7.0		7.0
Tax-effected interest expense		61.2		62.5		52.7		51.1		48.2
As-Reported Earnings including preferred dividends and tax-effected interest expense (B)		535.2		294.0		285.6		208.7		191.5
Special items
Nuclear alignment		-		-		-		-		(2.2	)
Total special items (C)		-		-		-		-		(2.2	)
Operational earnings including preferred dividends and tax-effected interest expense (B-C)		535.2		294.0		285.6		208.7		193.7
Operational earnings (A-C)		467.0		224.5		225.9		150.6		138.6
Average invested capital (D)		4,414		3,890		3,491		2,958		2,697
Average invested capital, excluding securitization (E)		4,311		3,890		3,491		2,958		2,697
Average members’ equity (F)		2,251		1,924		1,710		1,531		1,386
Gross debt (G)		2,297		1,830		1,902		1,462		1,192
Less securitization debt (H)		207		-		-		-		-
Gross debt, excluding securitization debt (G-H)		2,090		1,830		1,902		1,462		1,192
Less cash and cash equivalents (I)		1		123		152		139		0.3
Net debt, excluding securitization debt (G-H-I)		2,089		1,707		1,750		1,323		1,192
Total capitalization (J)		4,862		3,967		3,813		3,170		2,746
Less securitization debt (K)		207		-		-		-		-
Total capitalization, excluding securitization debt (J-K)		4,655		3,967		3,813		3,170		2,746
Less cash and cash equivalents (L)		1		123		152		139		0.3
Net capitalization, excluding securitization debt (J-K-L)		4,654		3,844		3,662		3,031		2,745
(%)
Return on average invested capital – As-Reported (B/D)		12.1		7.6		8.2		7.1		7.1
Return on average invested capital – Operational ((B-C)/E)		12.4		7.6		8.2		7.1		7.2
Return on average members’ equity – As-Reported (A/F)		20.7		11.7		13.2		9.8		9.8
Return on average members’ equity – Operational ((A-C)/F)		20.7		11.7		13.2		9.8		10.0
Debt to capital ratio (G/J)		47.2		46.1		49.9		46.1		43.4
Debt to capital ratio, excluding securitization debt ((G-H)/(J-K))		44.9		46.1		49.9		46.1		43.4
Net debt to net capital ratio, excluding securitization debt ((G-H-I)/(J-K-L))		44.9		44.4		47.8		43.6		43.4

Calculations may differ due to rounding.

66

REG G RECONCILIATIONS

ENTERGY MISSISSIPPI FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES

2007-2011

($ millions)	2011		2010		2009		2008		2007
As-Reported Earnings (A)		105.9		82.5		76.5		58.4		70.1
Preferred dividends		2.8		2.8		2.8		2.8		2.8
Tax-effected interest expense		29.5		32.1		30.5		27.7		27.4
As-Reported Earnings including preferred dividends and tax-effected interest expense (B)		138.3		117.4		109.9		88.9		100.2
Special items
		-		-		-		-		-
Total special items (C)		-		-		-		-		-
Operational earnings including preferred dividends and tax-effected interest expense (B-C)		138.3		117.4		109.9		88.9		100.2
Operational earnings (A-C)		105.9		82.5		76.5		58.4		70.1
Average invested capital (D)		1,720		1,609		1,509		1,418		1,439
Average common equity (E)		784		714		681		664		639
Gross debt (F)		931		839		852		703		704
Less cash and cash equivalents (G)		-		1		91		1		41
Net debt (F-G)		931		837		760		702		664
Total capitalization (H)		1,817		1,622		1,596		1,422		1,413
Less cash and cash equivalents (I)		-		1		91		1		41
Net capitalization (H-I)		1,817		1,621		1,505		1,421		1,373
(%)
Return on average invested capital – As-Reported (B/D)		8.0		7.3		7.3		6.3		7.0
Return on average invested capital – Operational ((B-C)/D)		8.0		7.3		7.3		6.3		7.0
Return on average common equity – As-Reported (A/E)		13.5		11.6		11.2		8.8		11.0
Return on average common equity – Operational ((A-C)/E)		13.5		11.6		11.2		8.8		11.0
Debt to capital ratio (F/H)		51.2		51.7		53.4		49.4		49.8
Net debt to net capital ratio ((F-G)/(H-I))		51.2		51.7		50.5		49.4		48.4

ENTERGY NEW ORLEANS FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES

2007-2011

($ millions)	2011		2010		2009		2008		2007
As-Reported Earnings (A)		35.0		30.1		29.5		33.4		23.0
Preferred dividends		1.0		1.0		1.0		1.0		1.1
Tax-effected interest expense		6.7		7.9		10.4		12.7		12.4
As-Reported Earnings including preferred dividends and tax-effected interest expense (B)		42.7		39.0		40.9		47.0		36.5
Special items
		-		-		-		-		-
Total special items (C)		-		-		-		-		-
Operational earnings including preferred dividends and tax-effected interest expense (B-C)		42.7		39.0		40.9		47.0		36.5
Operational earnings (A-C)		35.0		30.1		29.5		33.4		23.0
Average invested capital (D)		371		436		499		500		476
Average common equity (E)		185		197		207		192		164
Gross debt (F)		167		167		272		273		304
Less cash and cash equivalents (G)		10		55		191		137		92
Net debt (F-G)		157		112		81		136		212
Total capitalization (H)		367		375		497		501		499
Less cash and cash equivalents (I)		10		55		191		137		92
Net capitalization (H-I)		358		320		306		364		407
(%)
Return on average invested capital – As-Reported (B/D)		11.5		8.9		8.2		9.4		7.7
Return on average invested capital – Operational ((B-C)/D)		11.5		8.9		8.2		9.4		7.7
Return on average common equity – As-Reported (A/E)		19.0		15.3		14.3		17.4		14.1
Return on average common equity – Operational ((A-C)/E)		19.0		15.3		14.3		17.4		14.1
Debt to capital ratio (F/H)		45.3		44.6		54.8		54.5		60.9
Net debt to net capital ratio ((F-G)/(H-I))		43.8		35.1		26.5		37.3		52.1

Calculations may differ due to rounding.

67

REG G RECONCILIATIONS

SYSTEM ENERGY RESOURCES FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES

2007-2011

($ millions)	2011		2010		2009		2008		2007
As-Reported Net Income (A)		64.2		82.6		48.9		91.1		136.1
Preferred dividends		-		-		-		-		-
Tax-effected interest expense		25.5		29.9		26.7		33.9		34.5
As-Reported Net Income including preferred dividends and tax-effected interest expense (B)		89.7		112.5		75.6		125.0		170.6
Special items
Nuclear Alignment		-		-		-		-		(1.9	)
Total special items (C)		-		-		-		-		(1.9	)
Operational earnings including preferred dividends and tax-effected interest expense (B-C)		89.7		112.5		75.6		125.0		172.5
Operational earnings (A-C)		64.2		82.6		48.9		91.1		138.0
Average invested capital (D)		1,614		1,666		1,703		1,750		1,740
Average common equity (E)		806		821		843		859		860
Gross debt (F)		747		869		820		899		882
Less cash and cash equivalents (G)		185		264		264		103		105
Net debt (F-G)		562		605		556		796		777
Total capitalization (H)		1,548		1,681		1,650		1,755		1,744
Less cash and cash equivalents (I)		185		264		264		103		105
Net capitalization (H-I)		1,362		1,417		1,386		1,652		1,639
(%)
Return on average invested capital – As-Reported (B/D)		5.6		6.8		4.4		7.1		9.8
Return on average invested capital – Operational ((B-C)/D)		5.6		6.8		4.4		7.1		9.9
Return on average common equity – As-Reported (A/E)		8.0		10.1		5.8		10.6		15.8
Return on average common equity – Operational ((A-C)/E)		8.0		10.1		5.8		10.6		16.0
Debt to capital ratio (F/H)		48.3		51.7		49.7		51.2		50.6
Net debt to net capital ratio ((F-G)/(H-I))		41.2		42.7		40.1		48.2		47.4

ENTERGY WHOLESALE COMMODITIES FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES

2007-2011

($ millions)	2011			2010			2009			2008		2007
As-Reported Net Income (A)		488.6			486.7			638.5			795.6		583.2
Preferred dividends		3.2			2.7			2.6			2.7		3.4
Tax-effected interest expense		12.7			44.2			48.2			62.0		48.6
As-Reported Net Income including preferred dividends and tax-effected interest expense (B)		504.5			533.6			689.3			860.2		635.2
Special items
Nuclear alignment		-			-			-			-		(18.4	)
Non-utility nuclear spin-off expenses		-			(100.7	)		(44.0	)		-		-
Total special items (C)		-			(100.7	)		(44.0	)		-		(18.4	)
Operational earnings including preferred dividends and tax-effected interest expense (B-C)		504.5			634.3			733.3			860.2		653.6
Operational earnings (A-C)		488.6			587.4			682.5			795.6		601.6
Average invested capital (D)		6,200			5,720			5,201			5,023		4,754
Average common equity (E)		5,840			5,197			4,506			4,150		3,549
Gross debt (F)		274			306			568			650		924
Less cash and cash equivalents (G)		322			454			453			459		458
Net debt (F-G)		(49	)		(148	)		115			191		466
Total capitalization (H)		6,379			6,022			5,419			4,983		5,062
Less cash and cash equivalents (I)		322			454			453			459		458
Net capitalization (H-I)		6,057			5,568			4,965			4,524		4,604
(%)
Return on average invested capital – As-Reported (B/D)		8.1			9.3			13.3			17.1		13.4
Return on average invested capital – Operational ((B-C)/D)		8.1			11.1			14.1			17.1		13.7
Return on average common equity – As-Reported (A/E)		8.4			9.4			14.2			19.2		16.4
Return on average common equity – Operational ((A-C)/E)		8.4			11.3			15.1			19.2		17.0
Debt to capital ratio (F/H)		4.3			5.1			10.5			13.0		18.3
Net debt to net capital ratio ((F-G)/(H-I))		(0.8	)		(2.7	)		2.3			4.2		10.1

Calculations may differ due to rounding.

68

REG G RECONCILIATIONS

ENTERGY WHOLESALE COMMODITIES FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES

1Q10-4Q11

($ millions)	1Q11			2Q11			3Q11			4Q11			1Q10			2Q10			3Q10			4Q10
For the quarter:
As-Reported Net Income (A)		122.6			64.9			130.2			171.0			89.9			103.9			143.0			149.9
Less special items (B)		-			-			-			-			(54.3	)		(14.5	)		(25.2	)		(6.7	)
Operational earnings (A-B)		122.6			64.9			130.2			171.0			144.2			118.4			168.2			156.6
As-Reported Net Income, rolling 12 months (C)		519.4			480.4			467.5			488.6			558.0			577.3			534.7			486.7
Preferred dividends		2.7			2.7			2.7			3.2			2.6			2.7			2.7			2.7
Tax-effected interest expense		15.1			12.3			11.9			12.7			67.7			57.6			51.7			44.2
As-Reported Net Income, rolling 12 months including preferred dividends and tax-effected interest expense (D)		537.3			495.4			482.2			504.5			628.3			637.5			589.0			533.6
Special items in prior quarters		(46.4	)		(31.9	)		(6.7	)		-			(37.4	)		(76.6	)		(80.8	)		(94.0	)
Special items in current quarter		-			-			-			-			(54.3	)		(14.5	)		(25.2	)		(6.7	)
Total special items (E)		(46.4	)		(31.9	)		(6.7	)		-			(91.7	)		(91.1	)		(106.0	)		(100.7	)
Operational earnings, rolling 12 months including preferred dividends and tax-effected interest expense (D-E)		583.7			527.4			488.9			504.5			720.0			728.6			695.0			634.3
Operational earnings, rolling
12 months (C-E)		565.8			512.3			474.2			488.6			649.7			668.4			640.7			587.4
Average invested capital (F)		5,946			5,946			6,162			6,200			5,440			5,433			5,703			5,720
Average common equity (G)		5,445			5,494			5,817			5,840			4,743			4,789			5,148			5,197
Gross debt (H)		259			257			221			274			570			475			298			306
Less cash and cash equivalents (I)		265			299			507			322			588			317			363			454
Net debt (H-I)		(6	)		(41	)		(286	)		(49	)		(18	)		158			(65	)		(148	)
Total capitalization (J)		6,211			6,288			6,297			6,379			5,680			5,603			6,028			6,022
Less cash and cash equivalents (K)		265			299			507			322			588			317			363			454
Net capital (J-K)		5,946			5,989			5,789			6,057			5,092			5,286			5,665			5,568
(%)
Return on average invested capital –
As-Reported (D/F)		9.0			8.3			7.8			8.1			11.5			11.7			10.3			9.3
Return on average invested capital –
Operational ((D-E)/F)		9.8			8.9			7.9			8.1			13.2			13.4			12.2			11.1
Return on average common equity –
As-Reported (C/G)		9.5			8.7			8.0			8.4			11.8			12.1			10.4			9.4
Return on average common equity –
Operational ((C-E)/G)		10.4			9.3			8.2			8.4			13.7			14.0			12.4			11.3
Debt to capital ratio (H/J)		4.2			4.1			3.5			4.3			10.0			8.5			4.9			5.1
Net debt to net capital ratio ((H-I)/(J-K))		(0.1	)		(0.7	)		(4.9	)		(0.8	)		(0.4	)		3.0			(1.2	)		(2.7	)

Calculations may differ due to rounding.

69

REG G RECONCILIATIONS

ENTERGY WHOLESALE COMMODITIES OPERATIONAL ADJUSTED EBITDA – RECONCILIATION OF GAAP TO NON-GAAP MEASURES

1Q10-4Q11

($ millions)	1Q11		2Q11			3Q11			4Q11			1Q10			2Q10			3Q10			4Q10
Net Income (A)		123.2		65.6			130.9			172.2			90.5			104.6			143.7			150.6
Add back: interest expense (B)		4.8		4.6			5.3			5.9			51.9			9.2			5.9			4.7
Add back: income tax expense (C)		85.0		64.3			64.1			12.1			87.6			67.4			30.7			83.0
Add back: depreciation and amortization (D)		43.2		44.2			45.2			46.6			40.5			38.2			41.8			42.7
Subtract: interest and investment income (E)		30.9		33.1			33.6			38.9			49.5			39.9			43.2			38.6
Add back: decommissioning expense (F)		28.1		28.6			29.1			(4.4	)		26.2			26.6			27.1			27.6
Subtract: other than temporary impairments (G)		-		(0.1	)		(0.0	)		-			(0.2	)		(0.8	)		(0.2	)		(0.1	)
Adjusted EBITDA (A+B+C+D-E+F-G)		253.4		174.3			241.0			193.5			247.4			206.9			206.2			270.1
Add back: special items (H)		-		-			-			-			43.5			22.4			40.4			10.6
Operational adjusted EBITDA (A+B+C+D-E+F-G+H)		253.4		174.3			241.0			193.5			290.9			229.3			246.6			280.7

Totals may not foot due to rounding.

ENTERGY WHOLESALE COMMODITIES OPERATIONAL ADJUSTED EBITDA – RECONCILIATION OF GAAP TO NON-GAAP MEASURES

2007-2011

($ millions)	2011			2010			2009			2008			2007
Net Income (A)		491.8			489.4			641.1			798.2			586.6
Add back: interest expense (B)		20.6			71.8			78.3			100.8			80.8
Add back: income tax expense (C)		225.5			268.7			322.2			289.6			143.5
Add back: depreciation and amortization (D)		179.2			163.2			151.8			136.9			109.5
Subtract: interest and investment income (E)		136.5			171.2			196.5			163.2			150.0
Add back: decommissioning expense (F)		81.5			107.5			99.4			93.6			78.7
Subtract: other than temporary impairments (G)		(0.1	)		(1.4	)		(86.1	)		(49.6	)		(4.9	)
Adjusted EBITDA (A+B+C+D-E+F-G)		862.2			930.8			1,182.4			1,305.5			854.0
Add back: special items (H)		-			116.7			48.0			-			29.9
Operational adjusted EBITDA (A+B+C+D-E+F-G+H)		862.2			1,047.5			1,230.4			1,305.5			883.9

Totals may not foot due to rounding.

70

ENTERGY CORPORATION AND SUBSIDIARIES

INVESTOR NEWS

Entergy’s quarterly earnings results, webcasts, presentations, and other news and information of investor interest may be obtained by visiting the investor information page on Entergy’s corporate website at entergy.com or calling Entergy’s Investor Relations information line at 1-888-ENTERGY (368-3749).

INVESTOR RELATIONS

Security analysts, portfolio managers, and other members of the financial community may contact:

Paula Waters

Vice President, Investor Relations

Telephone: 504-576-4380

E–mail: pwater1@entergy.com

SHAREHOLDER ACCOUNT INFORMATION

Computershare is Entergy’s transfer agent, registrar, dividend disbursing agent, and dividend reinvestment and stock purchase plan agent. Shareholders of record with questions about lost certificates, lost or missing dividend checks or notifications of change of address should contact:

Computershare

480 Washington Boulevard

Jersey City, NJ 07310

Telephone: 1-800-333-4368

Internet address: www.computershare.com

CORPORATE GOVERNANCE

Entergy’s Corporate Governance Guidelines, Board Committee Charters for the Corporate Governance, Audit, and Personnel Committees, and Entergy’s Code of Conduct may be accessed electronically by selecting the investor information page on Entergy’s corporate website at entergy.com.

ADDITIONAL INFORMATION

For copies of the above Corporate Governance documents, Entergy’s 10-K and 10-Q reports filed with the Securities and Exchange Commission, or for other investor information, call 1-888-ENTERGY or write to:

Entergy Corporation

Investor Relations

P.O. Box 61000

New Orleans, LA 70161

COMMON STOCK INFORMATION

The company’s common stock is listed on the New York and Chicago exchanges under the symbol “ETR” (CUSIP 29364G10). The Entergy share price is reported daily in the financial press under “Entergy” in most listings of New York Stock Exchange securities. Entergy common stock is a component of the following indices: S&P 500, S&P Utilities Index, Philadelphia Utility Index and the NYSE Composite Index, among others.

As of January 31, 2012, there were 176,620,417 shares of Entergy common stock outstanding. Shareholders of record totaled 35,096, and approximately 55,000 investors held Entergy stock in “street name” through a broker.

CERTIFICATIONS

In May 2011, Entergy’s Chief Executive Officer certified to the New York Stock Exchange that he was not aware of any violation of the NYSE corporate governance listing standards. Also, Entergy filed certifications regarding the quality of the company’s public disclosure, required by Section 302 of the Sarbanes-Oxley Act of 2002, as exhibits to its Report on Form 10-K for the fiscal year ended December 31, 2011.

ENTERGY COMMON STOCK PRICES

The high and low trading prices for each quarterly period in 2011 and 2010 were as follows (in dollars):

	2011				2010
QUARTER	HIGH		LOW		HIGH		LOW
1		74.50		64.72		83.09		75.25
2		70.40		65.15		84.33		71.28
3		69.14		57.60		80.80		70.35
4		74.00		62.66		77.90		68.65

DIVIDEND PAYMENTS

The Board of Directors declares dividends quarterly and sets the record and payment dates. Subject to Board discretion, those dates for 2012 are:

DECLARATION DATE	RECORD DATE	PAYMENT DATE
January 27	February 9	March 1
April 4	May 10	June 1
July 27	August 9	September 4
October 26	November 8	December 3

Quarterly dividend payments (in cents-per-share):

QUARTER	2012		2011		2010		2009		2008
1		83		83		75		75		75
2		83		83		83		75		75
3				83		83		75		75
4				83		83		75		75

PREFERRED STOCK DIVIDEND PAYMENTS

The board of directors for each preferred stock issuer declares preferred dividends quarterly and sets the record and payment dates. Subject to their discretion, those dates for 2012 and 2013 are:

OPERATING COMPANIES	RECORD DATE		PAYMENT DATE
Entergy Arkansas, Inc.		12/26/11		1/3/12
		3/26/12		4/2/12
		6/20/12		7/2/12
		9/20/12		10/1/12
		12/20/12		1/1/13
		3/20/13		4/1/13
		6/20/13		7/1/13
		9/20/13		10/1/13
Entergy Gulf States Louisiana, L.L.C.		2/29/12		3/15/12
		5/31/12		6/15/12
		8/31/12		9/17/12
		11/30/12		12/17/12
		2/28/13		3/15/13
		5/31/13		6/17/13
		8/30/13		9/16/13
		11/29/13		12/16/13
Entergy Louisiana, LLC		2/29/12		3/15/12
		5/31/12		6/15/12
		8/31/12		9/17/12
		11/30/12		12/17/12
		2/28/13		3/15/13
		5/31/13		6/17/13
		8/30/13		9/16/13
		11/29/13		12/16/13
Entergy Mississippi, Inc.		1/20/12		2/1/12
		4/20/12		5/1/12
		7/20/12		8/1/12
		10/22/13		11/1/12
		1/21/13		2/1/13
		4/21/13		5/1/13
		7/22/13		8/1/13
		10/21/13		11/1/13
Entergy New Orleans, Inc.		12/26/11		1/3/12
		3/26/12		4/2/12
		6/20/12		7/2/12
		9/20/12		10/1/12
		12/20/12		1/1/13
		3/20/13		4/1/13
		6/20/13		7/1/13
		9/20/13		10/1/13

71