{\rtf1\deflang1033\deflangfe1033\margl720\margr720\margt360\margb360{\stylesheet{\fs20\lang1033\snext0 Normal;} {\s1\sb240\keepn{\*\pn \pnlvl1\pndec\pnprev1\pnstart1\pnsp144}\b\f0\fs30\lang1033 \sbasedon0\snext0 heading 1;} {\s2\sb200\keepn{\*\pn \pnlvl2\pndec\pnprev1\pnstart1\pnsp144{\pntxtb.}}\b\f0\fs26\lang1033 \sbasedon0\snext0 heading 2;} {\s3\sb180\keepn{\*\pn \pnlvl3\pndec\pnprev1\pnstart1\pnsp144{\pntxtb.}}\b\f0\fs22\lang1033 \sbasedon0\snext0 heading 3;} {\s4\sb160\keepn{\*\pn \pnlvl4\pnucltr\pnprev1\pnstart1\pnsp144{\pntxtb.}}\b\f0\fs22\lang1033 \sbasedon0\snext0 heading 4;} {\s5\sb140\keepn{\*\pn \pnlvl5\pncltr\pnprev1\pnstart1\pnsp144}\b\f0\fs20\lang1033 \sbasedon0\snext0 heading 5;} {\s6\tqc\lang1033\sbasedon0\snext6 footer;} {\*\cs16 \additive\super\sbasedon10 footnote reference;} {\*\cs18 \additive\sbasedon10 page number;}} {\fonttbl{\f0\fnil Times New Roman;}{\f1\fnil Courier New}{\f2005\fnil Courier New;}{\f2010\fnil Wingdings;}{\f2020\fnil Webdings;}{\f2\fnil Arial;}{\f3\fnil Arial;}{\f4\fnil LucidaHandwriting;}{\f5\fnil Symbol;}{\f6\fnil Symbol;}{\f7\fnil Ferdsch;}{\f30\fnil Myriad Cn Semibold;}{\f31\fnil Myriad Roman;}{\f50\fnil Courier New;}{\f51\fnil Times New Roman;}{\f52\fnil Arial;}{\f53\fnil Symbol;}{\f54\fnil Wingdings;}{\f55\fnil Wingdings 2;}{\f56\fnil Wingdings 3;}{\f57\fnil Webdings;}{\f58\fnil Arial Narrow;}{\f59\fnil Arial Unicode MS;}{\f60\fnil Cyberbit;}{\f61\fnil Morningstar 1U Light;}{\f62\fnil Calibri;}} {\colortbl;\red0\green0\blue0;\red127\green0\blue0;\red0\green0\blue255;\red127\green127\blue127;\red0\green51\blue153;\red255\green204\blue0;\red255\green255\blue255;\red246\green244\blue236;\red0\green0\blue0;} {\*\bkmkstart filing_1}{\*\bkmkend filing_1}{\*\bkmkstart doc_1_1}{\*\bkmkend doc_1_1} \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ______________________________________________________________________ \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql UNITED STATES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SECURITIES AND EXCHANGE COMMISSION \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Washington, D.C. 20549 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FORM 10-K \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (Mark One) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql X ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql THE SECURITIES EXCHANGE ACT OF 1934 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Fiscal Year Ended December 31, 2000 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OR \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TRANSITION REPORT PURSUANT TO SECTION 13 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the transition period from ____________ to ____________ \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Commission Registrant, State of Incorporation, IRS Employer \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql File Number Address of Principal Executive Identification No. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Offices and Telephone Number \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1-11299 ENTERGY CORPORATION 72-1229752 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a Delaware corporation) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 639 Loyola Avenue \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans, Louisiana 70113 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Telephone (504) 576-4000 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1-10764 ENTERGY ARKANSAS, INC. 71-0005900 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (an Arkansas corporation) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 425 West Capitol Avenue, 40th Floor \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Little Rock, Arkansas 72201 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Telephone (501) 377-4000 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1-27031 ENTERGY GULF STATES, INC. 74-0662730 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a Texas corporation) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 350 Pine Street \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Beaumont, Texas 77701 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Telephone (409) 838-6631 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1-8474 ENTERGY LOUISIANA, INC. 72-0245590 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a Louisiana corporation) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 4809 Jefferson Highway \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Jefferson, Louisiana 70121 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Telephone (504) 840-2734 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 0-320 ENTERGY MISSISSIPPI, INC. 64-0205830 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a Mississippi corporation) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 308 East Pearl Street \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Jackson, Mississippi 39201 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Telephone (601) 368-5000 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 0-5807 ENTERGY NEW ORLEANS, INC. 72-0273040 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a Louisiana corporation) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1600 Perdido Street, Building 505 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans, Louisiana 70112 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Telephone (504) 670-3674 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1-9067 SYSTEM ENERGY RESOURCES, INC. 72-0752777 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (an Arkansas corporation) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Echelon One \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1340 Echelon Parkway \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Jackson, Mississippi 39213 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Telephone (601) 368-5000 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ______________________________________________________________________ \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Securities registered pursuant to Section 12(b) of the Act: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Name of Each Exchange \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Registrant Title of Class on Which Registered \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Entergy Corporation Common Stock, $0.01 Par Value - 220,062,294 New York Stock Exchange, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql shares outstanding at February 28, 2001 Chicago Stock Exchange Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Pacific Exchange Inc. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Entergy Arkansas Capital I 8-1/2% Cumulative Quarterly Income Preferred New York Stock Exchange, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Securities, Series A \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Entergy Gulf States, Inc. Preferred Stock, Cumulative, $100 Par Value: \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql $4.40 Dividend Series New York Stock Exchange, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql $4.52 Dividend Series New York Stock Exchange, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql $5.08 Dividend Series New York Stock Exchange, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Adjustable Rate Series B (Depository Receipts) New York Stock Exchange, Inc. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Entergy Gulf States Capital I 8.75% Cumulative Quarterly Income Preferred New York Stock Exchange, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Securities, Series A \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Entergy Louisiana Capital I 9% Cumulative Quarterly Income Preferred New York Stock Exchange, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Securities, Series A \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Securities registered pursuant to Section 12(g) of the Act: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Registrant Title of Class \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Inc. Preferred Stock, Cumulative, $100 Par Value \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred Stock, Cumulative, $0.01 Par Value \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States, Inc. Preferred Stock, Cumulative, $100 Par Value \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana, Inc. Preferred Stock, Cumulative, $100 Par Value \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred Stock, Cumulative, $25 Par Value \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi, Inc. Preferred Stock, Cumulative, $100 Par Value \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans, Inc. Preferred Stock, Cumulative, $100 Par Value \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Indicate by check mark whether the registrants (1) have filed all \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reports required to be filed by Section 13 or 15(d) of the Securities \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Exchange Act of 1934 during the preceding 12 months (or for such shorter \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql period that the registrants were required to file such reports), and (2) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql have been subject to such filing requirements for the past 90 days. Yes \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql No ____ \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Indicate by check mark if disclosure of delinquent filers pursuant to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Item 405 of Regulation S-K is not contained herein, and will not be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contained, to the best of the registrants' knowledge, in definitive proxy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql or information statements incorporated by reference in Part III of this \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Form 10-K or any amendment to this Form 10-K. [ ] \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The aggregate market value of Entergy Corporation Common Stock, $0.01 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Par Value, held by non-affiliates, was $8.5 billion based on the reported \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql last sale price of such stock on the New York Stock Exchange on February \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 28, 2001. Entergy Corporation is directly or indirectly the sole holder of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the common stock of Entergy Arkansas, Inc., Entergy Gulf States, Inc., \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana, Inc., Entergy Mississippi, Inc., Entergy New Orleans, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Inc., and System Energy Resources, Inc. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql DOCUMENTS INCORPORATED BY REFERENCE \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Portions of the Proxy Statement of Entergy Corporation to be filed in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql connection with its Annual Meeting of Stockholders, to be held May 11, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2001, are incorporated by reference into Parts I and III hereof. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TABLE OF CONTENTS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Number \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Definitions i \par\pard\plain\fs16{\*\bkmkstart part_1_2_1}{\*\bkmkend part_1_2_1}\pard\plain\cf1\f50\fs16\ql Part I \par\pard\plain\fs16{\*\bkmkstart item_1_3_1}{\*\bkmkend item_1_3_1}\pard\plain\cf1\f50\fs16\ql Item 1. Business 1 \par\pard\plain\fs16{\*\bkmkstart part_1_2_2}{\*\bkmkend part_1_2_2}{\*\bkmkstart item_1_3_2}{\*\bkmkend item_1_3_2}\pard\plain\cf1\f50\fs16\ql Item 2. Properties 36 \par\pard\plain\fs16{\*\bkmkstart part_1_2_3}{\*\bkmkend part_1_2_3}{\*\bkmkstart item_1_3_3}{\*\bkmkend item_1_3_3}\pard\plain\cf1\f50\fs16\ql Item 3. Legal Proceedings 36 \par\pard\plain\fs16{\*\bkmkstart part_1_2_4}{\*\bkmkend part_1_2_4}{\*\bkmkstart item_1_3_4}{\*\bkmkend item_1_3_4}\pard\plain\cf1\f50\fs16\ql Item 4. Submission of Matters to a Vote of Security Holders 36 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Directors and Executive Officers of Entergy Corporation 37 \par\pard\plain\fs16{\*\bkmkstart part_1_2_5}{\*\bkmkend part_1_2_5}\pard\plain\cf1\f50\fs16\ql Part II \par\pard\plain\fs16{\*\bkmkstart item_1_3_5}{\*\bkmkend item_1_3_5}\pard\plain\cf1\f50\fs16\ql Item 5. Market for Registrants' Common Equity and Related \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Stockholder Matters 39 \par\pard\plain\fs16{\*\bkmkstart item_1_3_6}{\*\bkmkend item_1_3_6}\pard\plain\cf1\f50\fs16\ql Item 6. Selected Financial Data 40 \par\pard\plain\fs16{\*\bkmkstart item_1_3_7}{\*\bkmkend item_1_3_7}\pard\plain\cf1\f50\fs16\ql Item 7. Management's Discussion and Analysis of Financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Condition and Results of Operations 40 \par\pard\plain\fs16{\*\bkmkstart item_1_3_8}{\*\bkmkend item_1_3_8}\pard\plain\cf1\f50\fs16\ql Item 7A.Quantitative and Qualitative Disclosures About Market \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Risk 40 \par\pard\plain\fs16{\*\bkmkstart item_1_3_9}{\*\bkmkend item_1_3_9}\pard\plain\cf1\f50\fs16\ql Item 8. Financial Statements and Supplementary Data 41 \par\pard\plain\fs16{\*\bkmkstart item_1_3_10}{\*\bkmkend item_1_3_10}\pard\plain\cf1\f50\fs16\ql Item 9. Changes in and Disagreements with Accountants on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accounting and Financial Disclosure 210 \par\pard\plain\fs16{\*\bkmkstart part_1_2_6}{\*\bkmkend part_1_2_6}\pard\plain\cf1\f50\fs16\ql Part III \par\pard\plain\fs16{\*\bkmkstart item_1_3_11}{\*\bkmkend item_1_3_11}\pard\plain\cf1\f50\fs16\ql Item 10.Directors and Executive Officers of the Registrants 210 \par\pard\plain\fs16{\*\bkmkstart part_1_2_7}{\*\bkmkend part_1_2_7}{\*\bkmkstart item_1_3_12}{\*\bkmkend item_1_3_12}\pard\plain\cf1\f50\fs16\ql Item 11.Executive Compensation 214 \par\pard\plain\fs16{\*\bkmkstart part_1_2_8}{\*\bkmkend part_1_2_8}{\*\bkmkstart item_1_3_13}{\*\bkmkend item_1_3_13}\pard\plain\cf1\f50\fs16\ql Item 12.Security Ownership of Certain Beneficial Owners and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management 228 \par\pard\plain\fs16{\*\bkmkstart item_1_3_14}{\*\bkmkend item_1_3_14}\pard\plain\cf1\f50\fs16\ql Item 13.Certain Relationships and Related Transactions 230 \par\pard\plain\fs16{\*\bkmkstart part_1_2_9}{\*\bkmkend part_1_2_9}\pard\plain\cf1\f50\fs16\ql Part IV \par\pard\plain\fs16{\*\bkmkstart item_1_3_15}{\*\bkmkend item_1_3_15}\pard\plain\cf1\f50\fs16\ql Item 14.Exhibits, Financial Statement Schedules, and Reports \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql on Form 8-K 232 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Signatures 233 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Report of Independent Accountants on Financial Statement Schedules 241 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Index to Financial Statement Schedules S-1 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Exhibit Index E-1 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql This combined Form 10-K is separately filed by Entergy Corporation, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Inc., Entergy Gulf States, Inc., Entergy Louisiana, Inc., \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi, Inc., Entergy New Orleans, Inc., and System Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Resources, Inc. Information contained herein relating to any individual \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql company is filed by such company on its own behalf. Each company makes \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql representations only as to itself and makes no other representations \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql whatsoever as to any other company. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql This report should be read in its entirety. No one section of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql report deals with all aspects of the subject matter. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FORWARD-LOOKING INFORMATION \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The following constitutes a "Safe Harbor" statement under the Private \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Securities Litigation Reform Act of 1995: Investors are cautioned that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql forward-looking statements contained herein with respect to the revenues, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql earnings, performance, strategies, prospects and other aspects of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql business of Entergy Corporation, Entergy Arkansas, Inc., Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States, Inc., Entergy Louisiana, Inc., Entergy Mississippi, Inc., Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans, Inc., and System Energy Resources, Inc. and their affiliated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies may involve risks and uncertainties. A number of factors could \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cause actual results or outcomes to differ materially from those indicated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by such forward-looking statements. These factors include, but are not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql limited to, risks and uncertainties relating to: the effects of weather, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the performance of generating units and transmission systems, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql possession of nuclear materials, fuel and purchased power prices and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql availability, the effects of regulatory decisions and changes in law, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql litigation, capital spending requirements, the onset of competition, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql including the ability to recover net regulatory assets and other potential \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql stranded costs, the effects of recent developments in the California \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql electricity market on the utility industry nationally, advances in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql technology, changes in accounting standards, corporate restructuring and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql changes in capital structure, consummation of the business combination with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FPL Group, Inc., consummation of the Koch Industries joint venture, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql success of new business ventures, changes in the markets for electricity \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and other energy-related commodities, changes in interest rates and in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial and foreign currency markets generally, the economic climate and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql growth in Entergy's service territories, changes in corporate strategies, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and other factors. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql DEFINITIONS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Certain abbreviations or acronyms used in the text and notes are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql defined below: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Abbreviation or Acronym Term \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql AFUDC Allowance for Funds Used During Construction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Algiers 15th Ward of the City of New Orleans, Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ALJ Administrative Law Judge \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ANO 1 and 2 Units 1 and 2 of Arkansas Nuclear One Steam \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Electric Generating Station (nuclear), owned by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql APB Accounting Principles Board \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql APSC Arkansas Public Service Commission \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Availability \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement Agreement, dated as of June 21, 1974, as amended, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql among System Energy and Entergy Arkansas, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana, Entergy Mississippi, and Entergy New Orleans, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and the assignments thereof \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Board Board of Directors of Entergy Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Boston Edison Boston Edison Company \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql BPS British pounds sterling \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cajun Cajun Electric Power Cooperative, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Capital Funds \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement Agreement, dated as of June 21, 1974, as amended, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql between System Energy and Entergy Corporation, and the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql assignments thereof \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql CitiPower CitiPower Pty., an electric distribution company \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql serving Melbourne, Australia and surrounding \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql suburbs, which was acquired by Entergy effective \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql January 5, 1996, and was sold by Entergy effective \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Council Council of the City of New Orleans, Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql D.C. Circuit United States Court of Appeals for the District of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Columbia Circuit \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql DOE United States Department of Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi, and Entergy New Orleans, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql collectively \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql EITF Emerging Issues Task Force \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql EMF Electromagnetic fields \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENHC Entergy Nuclear Holding Company #1 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql EPA United States Environmental Protection Agency \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql EPAct Energy Policy Act of 1992 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql EPDC Entergy Power Development Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql EPMC Entergy Power Marketing Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ET&M Entergy Trading and Marketing, Ltd. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ETHC Entergy Technology Holding Company \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql EWG Exempt wholesale generator under PUHCA \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Entergy Corporation and its various direct and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql indirect subsidiaries \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas Entergy Arkansas, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation Entergy Corporation, a Delaware corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States Entergy Gulf States, Inc., including its wholly \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql owned subsidiaries - Varibus Corporation, GSG&T, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Inc., Prudential Oil & Gas, Inc., and Southern \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf Railway Company \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy London Entergy London Investments plc, formerly Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Power UK plc (including its wholly owned \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql subsidiary, London Electricity plc), which was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql sold by Entergy effective December 4, 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana Entergy Louisiana, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi Entergy Mississippi, Inc. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql DEFINITIONS (Continued) \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Abbreviation or Acronym Term \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans Entergy New Orleans, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Nuclear Entergy Nuclear, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Nuclear \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operations Entergy Nuclear Operations, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Operations Entergy Operations, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Power Entergy Power, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Services Entergy Services, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FASB Financial Accounting Standards Board \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FERC Federal Energy Regulatory Commission \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FitzPatrick James A. FitzPatrick nuclear power plant, 825 MW \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql facility located near Oswego, New York, purchased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in November 2000 from New York Power Authority by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's domestic non-utility nuclear business \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FPL Group FPL Group, Inc., a Florida corporation and parent \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql company of Florida Power & Light Company \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FUCO Exempt foreign utility company under PUHCA \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Grand Gulf 1 and 2 Units 1 and 2 of Grand Gulf Steam Electric \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Generating Station (nuclear), 90% owned or leased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by System Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql GWH one million kilowatt-hours \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Independence Independence Steam Electric Station (coal), owned \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 16% by Entergy Arkansas, 25% by Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, and 7% by Entergy Power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Indian Point 3 Indian Point 3 nuclear power plant, 980 MW \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql facility located in Westchester County, New York, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchased in November 2000 from New York Power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Authority by Entergy's domestic non-utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql nuclear business \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql IRS Internal Revenue Service \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql KV kilovolt \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql KW kilowatt \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql KWH kilowatt-hour(s) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql London Electricity London Electricity plc - a regional electric \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql company serving London, England, which was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql acquired by Entergy London effective February 1, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1997, and was sold by Entergy effective December \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 4, 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LDEQ Louisiana Department of Environmental Quality \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LPSC Louisiana Public Service Commission \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MCF 1,000 cubic feet of gas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Merger The business combination transaction pursuant to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql which the outstanding shares of FPL Group and the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql outstanding shares of Entergy Corporation will be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql converted into 1.00 and 0.585 shares, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql respectively, of a new company \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Merger Agreement Agreement and Plan of Merger dated July 30, 2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by and between FPL Group, Entergy Corporation, WCB \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Holding Corporation, Ranger Acquisition \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Corporation and Ring Acquisition Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MPSC Mississippi Public Service Commission \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MW Megawatt(s) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql N/A Not applicable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nelson Unit 6 Unit No. 6 (coal) of the Nelson Steam Electric \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Generating Station, owned 70% by Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql NERC North American Electric Reliability Council \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql NISCO Nelson Industrial Steam Company \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql NRC Nuclear Regulatory Commission \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql NYPA New York Power Authority \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql DEFINITIONS (Concluded) \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Abbreviation or Acronym Term \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Pilgrim Pilgrim Nuclear Station, 670 MW facility located \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in Plymouth, Massachusetts, purchased in July 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql from Boston Edison by Entergy's domestic non- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility nuclear business \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PRP Potentially Responsible Party (a person or entity \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that may be responsible for remediation of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql environmental contamination) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PUCT Public Utility Commission of Texas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PUHCA Public Utility Holding Company Act of 1935, as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amended \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PURPA Public Utility Regulatory Policies Act of 1978 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Reallocation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement 1981 Agreement, superseded in part by a June 13, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1985 decision of FERC, among Entergy Arkansas, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana, Entergy Mississippi, Entergy New Orleans, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and System Energy relating to the sale of capacity and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql energy from Grand Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Ritchie 2 Unit 2 of the R. E. Ritchie Steam Electric \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Generating Station (gas/oil) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql River Bend River Bend Steam Electric Generating Station \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (nuclear) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SEC Securities and Exchange Commission \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SFAS Statement of Financial Accounting Standards, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql promulgated by the FASB \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SMEPA South Mississippi Electric Power Agency, which \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql owns the remaining 10% interest in Grand Gulf 1 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Agreement Agreement, effective January 1, 1983, as modified, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql among the domestic utility companies relating to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the sharing of generating capacity and other power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql resources \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy System Energy Resources, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Fuels System Fuels, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Tons/hr Tons per hour, used as a measure of steam \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql production \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql UK The United Kingdom of Great Britain and Northern \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Ireland \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Unit Power Sales \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement Agreement, dated as of June 10, 1982, as amended and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approved by FERC, among Entergy Arkansas, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana, Entergy Mississippi, Entergy New Orleans, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and System Energy, relating to the sale of capacity \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and energy from System Energy's share of Grand Gulf 1 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Waterford 3 Unit No. 3 (nuclear) of the Waterford Steam \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Electric Generating Station, 100% owned or leased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by Entergy Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql White Bluff White Bluff Steam Electric Generating Station, 57% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql owned by Entergy Arkansas \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page{\*\bkmkstart part_1_2_10}{\*\bkmkend part_1_2_10}\par\pard\plain\cf1\f50\fs16\ql PART I \par\pard\plain\fs16{\*\bkmkstart item_1_3_16}{\*\bkmkend item_1_3_16}\pard\plain\cf1\f50\fs16\ql Item 1. Business \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql BUSINESS OF ENTERGY \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation is a Delaware corporation which, through its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql subsidiaries, engages principally in the following businesses: domestic \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility, power marketing and trading, global power development, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic non-utility nuclear. Power marketing and trading, global power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql development, and domestic non-utility nuclear are sometimes referred to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql as the competitive businesses. In 2000, Entergy placed the management of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the power marketing and trading business under the global power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql development business, and the jointly-managed businesses are referred to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql as Entergy Wholesale Operations. Entergy Corporation has no significant \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql assets other than the stock of its subsidiaries. Entergy Corporation is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql a registered public utility holding company under PUHCA. As such, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation and its subsidiaries generally are subject to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql broad regulatory provisions of PUHCA. PUHCA generally limits registered \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql public utility holding company activity to direct and indirect ownership \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of domestic integrated utility businesses, domestic and foreign electric \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generation ventures, foreign utility ownership, telecommunications and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql information service businesses, and certain other domestic energy related \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql businesses. Financial information regarding Entergy Corporation's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operating segments is contained in Note 14 to the financial statements. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In December 2000, Entergy's shareholders approved a business combination \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql between Entergy Corporation and FPL Group, the objective of which is the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql creation of a new company. See "Business Combination with FPL Group" for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql further discussion of the terms and timing of this transaction. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Domestic Utility \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The domestic utility is Entergy's predominant business segment, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql providing 74% of its revenue and 87% of its net income in 2000, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql holding 81% of its assets as of December 31, 2000. Entergy Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql has five wholly-owned domestic retail electric utility subsidiaries: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, and Entergy New Orleans. As of December 31, 2000, these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility companies provided retail electric service to approximately 2.6 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million customers primarily in portions of the states of Arkansas, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana, Mississippi, and Texas. In addition, Entergy Gulf States \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql furnishes natural gas utility service in and around Baton Rouge, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana, and Entergy New Orleans furnishes natural gas utility service \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in New Orleans, Louisiana. The business of the domestic utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies is subject to seasonal fluctuations, with the peak sales period \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql normally occurring during the third quarter of each year. During 2000, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the domestic utility companies' combined retail electric sales volumes as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql a percentage of total electric sales volumes were: residential - 28.3%; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commercial - 21.8%; and industrial - 38.8%. Retail electric revenues \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql from these sectors as a percentage of total electric revenues were: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql residential - 35.0%; commercial - 23.5%; and industrial - 30.2%. Sales \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to governmental and municipal sectors and to nonaffiliated utilities \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accounted for the balances of energy sales and electric revenues. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql major industrial customers of the domestic utility companies are in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql chemical, petroleum refining, paper, and food products industries. State \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql or local regulatory authorities regulate the retail rates and services of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's domestic retail utility subsidiaries. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation also owns 100% of the voting stock of System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Energy, an Arkansas corporation that owns and leases an aggregate 90% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql undivided interest in Grand Gulf. System Energy sells all of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql capacity and energy from its interest in Grand Gulf 1 at wholesale to its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql only customers, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and Entergy New Orleans. Management discusses sales from Grand Gulf 1 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql more thoroughly in "CAPITAL REQUIREMENTS AND FUTURE FINANCING - Certain \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Grand Gulf-related Financial and Support Agreements - Unit Power Sales \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement" below. System Energy's wholesale power sales are subject to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the jurisdiction of FERC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Services, a Delaware corporation wholly-owned by Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Corporation, provides management, administrative, accounting, legal, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql engineering, and other services primarily to the domestic utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql subsidiaries of Entergy Corporation. Entergy Operations, a Delaware \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql corporation, is also wholly-owned by Entergy Corporation and provides \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql nuclear management, operations and maintenance services under contract \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for ANO, River Bend, Waterford 3, and Grand Gulf 1, subject to the owner \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql oversight of Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and System Energy, respectively. Entergy Arkansas, Entergy Louisiana, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi, and Entergy New Orleans own 35%, 33%, 19%, and 13%, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql respectively, of the common stock of System Fuels, a Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql corporation that implements and manages certain programs to procure, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deliver, and store fuel supplies for those companies. Entergy Services, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Operations, and System Fuels provide their services to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility companies and System Energy on an "at cost" basis, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql pursuant to service agreements approved by the SEC under PUHCA. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Information regarding affiliate transactions is contained in Note 13 to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States has wholly-owned subsidiaries that (i) own and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operate intrastate gas pipelines in Louisiana used primarily to transport \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel to two of Entergy Gulf States' generating stations; (ii) own the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Lewis Creek Station, a gas-fired generating plant, which is leased to and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operated by Entergy Gulf States; and (iii) own several miles of railroad \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql track constructed in Louisiana primarily for the purpose of transporting \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql coal for use as boiler fuel at Entergy Gulf States' Nelson Unit 6 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generating facility. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Power Marketing and Trading \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Prior to 2001, Entergy conducted its power marketing and trading \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql business primarily through three subsidiaries, Entergy Power, EPMC, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ET&M. Entergy Power is a domestic power producer that owns 665 MW of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fossil-fueled generation assets located in Arkansas. Entergy Power's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql capacity and energy is sold at wholesale principally to EPMC and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas. Entergy Power's wholesale power sales are subject to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql jurisdiction of FERC. EPMC engages in the marketing and trading of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql physical and financial energy commodity products, industrial energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql management, and risk management services. It has authority from the SEC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to deal in a wide range of energy commodities and related financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql products. ET&M is engaged in the marketing and trading of physical and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial energy commodity products in the UK. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql On January 31, 2001, Entergy contributed its power marketing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and trading business to a new limited partnership, Entergy-Koch, L.P. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The joint venture is with Koch Industries, Inc., which contributed to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql venture its 9,000-mile Koch Gateway Pipeline (which has been renamed the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf South Pipeline), gas storage facilities including the Bistineau \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql storage facility near Shreveport, Louisiana, and Koch Energy Trading, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql which markets and trades electricity, gas, weather derivatives, and other \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql energy-related commodities and services (the joint venture's trading \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql activities are now conducted under the name Axia Energy). The parties \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql have equal ownership interests in Entergy-Koch, L.P., which is governed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by an eight-member board of directors. Entergy appointed four members of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the board. The partnership agreement allocates the substantial majority \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Entergy-Koch, L.P.'s earnings through 2003 to Entergy. Losses are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generally allocated equally. Entergy Power was not transferred to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql joint venture, and it was placed under the management of the global power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql development business. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Global Power Development \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's global power development business is focused on acquiring \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql or developing power generation projects in North America and Western \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Europe. The Latin American projects owned by the global power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql development business are not a core part of its strategy, and Entergy is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql considering various strategies to maximize the value of these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql investments, including possibly selling them. The global power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql development business owns interests in the following electric generation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql assets that are currently operating or are under construction: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Investment Percent Ownership Status \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Argentina - Costanera, 1,260 MW 6% operational \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Argentina - Costanera expansion, 220 MW 10% operational \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Chile - San Isidro, 375 MW 25% operational \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Pakistan - Hub River, 1,200 MW 5% operational \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Peru - Edegel - 833 MW 24% operational \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql United Kingdom - Saltend, 1,200 MW 100% operational \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql United Kingdom - Damhead Creek, 800 MW 100% operational \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql U.S. (AR) - Ritchie Unit 2, 544 MW 100% operational \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql U.S. (AR) - Independence Unit 2, 840 MW 14% operational \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql U.S. (LA) - Riverside, 425 MW 50% under construction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql U.S. (MS) - Warren Power, 300 MW 100% under construction \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Damhead Creek commenced commercial operation in 2001. Entergy Power owns \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Ritchie Unit 2 and the interest in Independence Unit 2. Entergy owns its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql interest in Riverside through a 50% interest in RS Cogen, LLC, and the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql remaining 50% interest is owned by PPG Industries, an industrial customer \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Entergy Gulf States. Entergy's global power development business has \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql several other development projects in the planning stages, including \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql announced projects in the United States, Spain, and Bulgaria. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In preparation for its global power development plans, Entergy has \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql obtained an option to acquire turbines from GE Power Systems. See \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - LIQUIDITY AND CAPITAL \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESOURCES" for further information on the turbines. Furthermore, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql global power development business entered into a 50/50 joint venture with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The Shaw Group Inc. that is named EntergyShaw, L.L.C. EntergyShaw \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql provides management, engineering, procurement, construction, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commissioning services for electric power plants. EntergyShaw plans to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operate in the rapidly growing electric power generation market and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql provide services for Entergy's global power development plans. In June \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, Entergy also acquired a 75% interest in Highland Energy Company, an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql energy aggregation, marketing, and producer services company. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In June 2000, the global power development business sold its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql interest in Freestone, a planned 1,000 MW combined cycle gas turbine \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql merchant power plant to be constructed in Fairfield, Texas, adjacent to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States' service territory. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Domestic Non-Utility Nuclear \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's domestic non-utility nuclear business is focused on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql acquiring, owning, operating, and selling power from nuclear power plants \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and providing operations and management services to nuclear power plants \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql owned by other utilities in the United States. Plant acquisitions are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql made through Entergy's wholly owned subsidiary ENHC and its affiliates. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operations and management services, including decommissioning services, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql are provided through Entergy's wholly owned subsidiary, Entergy Nuclear. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's domestic non-utility nuclear business owns the following \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql nuclear power plants that it has acquired from other utilities: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Power Plant Capacity Percent Ownership Location \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Pilgrim Nuclear Station 670 MW 100% Plymouth, MA \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql James A. FitzPatrick 825 MW 100% Oswego, NY \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Indian Point 3 980 MW 100% Westchester County, NY \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Pilgrim has firm power purchase agreements with Boston Edison and other \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utilities that expire at the end of 2004. One hundred percent of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql plant's output is committed to those parties through 2001, and that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commitment decreases to 50% by 2003. Indian Point 3 has a firm power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchase agreement with NYPA that expires at the end of 2004 for 100% of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the plant's output. FitzPatrick has firm power purchase agreements with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql NYPA that expire at the end of 2004 for 100% of the plant's output \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql through 2003 and approximately 45% of the plant's output in 2004. See \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Note 12 to the financial statements for a further discussion of these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql acquisitions by Entergy's domestic non-utility nuclear business. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In November 2000, Entergy's domestic non-utility nuclear business \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql agreed to purchase Consolidated Edison's (Con Edison) 957 MW Indian Point \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2 nuclear power plant (IP2) located in Westchester County, New York. In \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the transaction, Entergy has agreed to acquire Indian Point 1 nuclear \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power plant (IP1), which has been shut down and in safe storage since the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql early 1970s. Entergy will pay $600 million in cash at the closing of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchase and will receive the plant, nuclear fuel, and other assets, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql including a purchase power agreement (PPA). Under the PPA, Con Edison \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql will purchase 100% of IP2's output through 2004. Con Edison will also \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transfer a $430 million decommissioning trust fund, along with the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql liability to decommission IP2 and IP1, to Entergy's nuclear business. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management expects to close the acquisition by mid-2001, pending the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approvals of the NRC, the New York Public Service Commission, and other \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulatory agencies. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In January 2001, Entergy's domestic non-utility nuclear business \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql submitted an offer to buy Vermont Yankee, a 540 MW boiling water reactor \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql plant, located in Vernon, Vermont, for $50 million. Entergy's offer is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql firm through the end of 2001. In February 2001, the Vermont Public \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Service Board rejected a competing offer and the plant is expected to be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql auctioned during the second or third quarter of 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Nuclear provides services to nuclear power plants owned by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql other utilities, including engineering, operations and maintenance, fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql procurement, management and supervision, technical support and training, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql administrative support, and other managerial or technical services \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql required to operate, maintain, and decommission nuclear electric power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql facilities. Currently Entergy is providing decommissioning services for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Maine Yankee and Millstone Unit 1 nuclear power plants. The cost of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decommissioning and insuring the plants that Entergy provides \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decommissioning services for is the responsibility of the plant owners. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, Entergy Nuclear entered into two business arrangements to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql assist it in providing operation and management services. Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nuclear and Framatome Technologies intend to jointly offer operating \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql license renewal and life extension services to nuclear power plants in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the United States. Framatome has provided and continues to provide \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql license renewal services to several utilities owning nuclear power plants \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in the United States. Entergy Nuclear also acquired TLG Services in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql September 2000. TLG provides decommissioning, engineering, and related \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql services to nuclear power plant owners. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Domestic and Foreign Generation Investment Restrictions and Risks \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's ability to invest in domestic and foreign generation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql businesses is subject to the SEC's regulations under PUHCA. Absent SEC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approval, these regulations limit Entergy Corporation's aggregate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql investment in domestic and foreign generation businesses at the time an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql investment is made to an amount equal to 50% of average consolidated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql retained earnings for the previous four quarters. In June 2000, the SEC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql issued an order that allows Entergy's EWG and FUCO investments to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increase from 50% to 100% of Entergy's average consolidated retained \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql earnings. As of December 31, 2000 Entergy's investments under this rule \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql totaled $770 million constituting 25% of its average consolidated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql retained earnings. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's ability to guarantee obligations of its non-utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql subsidiaries is also limited by SEC regulations under PUHCA. In August \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, the SEC issued an order, effective through December 31, 2005, that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql allows Entergy to issue up to $2 billion of guarantees to its non-utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies, excluding guarantees outstanding as of that date that were \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql issued under a previous order. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql International operations are subject to the risks inherent in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql conducting business abroad, including possible nationalization or \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expropriation, price and currency exchange controls, inflation, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql limitations on foreign participation in local enterprises, and other \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql restrictions. Changes in the relative value of currencies may favorably \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql or unfavorably affect the financial condition and results of operations \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Entergy's non-U.S. businesses. In addition, exchange control \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql restrictions in certain countries may limit or prevent the repatriation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of earnings. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Business Combination with FPL Group \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql On July 30, 2000, Entergy Corporation and FPL Group entered into a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Merger Agreement providing for a business combination that will result in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the creation of a new company. Each outstanding share of FPL Group \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql common stock will be converted into one share of the new company's common \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql stock, and each outstanding share of Entergy Corporation common stock \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql will be converted into 0.585 of a share of the new company's common \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql stock. It is expected that FPL Group's shareholders will own \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approximately 57% of the common equity of the new company and Entergy's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql shareholders will own approximately 43%. The initial board of directors \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the new company will consist of eight directors designated by FPL \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Group and seven directors designated by Entergy. The new company will be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql given a new name that will be agreed upon between the Boards of Directors \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of FPL and Entergy prior to the consummation of the Merger. The new \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql company will maintain its principal corporate offices and headquarters in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Juno Beach, Florida, and will maintain its utility headquarters in New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans, Louisiana. The Merger Agreement generally allows Entergy to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql continue business in the ordinary course consistent with past practice \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and contains certain restrictions on Entergy's capital activities, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql including restrictions on the issuance of securities, capital \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expenditures, dispositions, incurrence or guarantee of indebtedness, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql trading or marketing of energy. Entergy generally will be permitted to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql take actions pursuant to restructuring legislation in the domestic \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility companies' jurisdictions of operation and to reorganize its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmission business. Under certain circumstances, if the Merger \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement is terminated, a termination fee of $215 million may be payable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by one of the parties. The Merger Agreement may be terminated if the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Merger is not consummated by April 30, 2002, unless automatically \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql extended until October 30, 2002 under certain circumstances. Both the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FPL Group and Entergy Boards of Directors unanimously approved the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Merger, and the shareholders of Entergy Corporation and FPL Group have \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approved the Merger. The Merger is conditioned upon, among other things, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the receipt of required regulatory approvals of various local, state, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql federal regulatory agencies and commissions, including the SEC and FERC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy has filed for approval of the Merger in all of its state and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql local regulatory jurisdictions (Arkansas, Louisiana, Mississippi, Texas, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and New Orleans), and at FERC, the SEC, and the NRC. In their filing with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the SEC, Entergy and FPL Group requested to remain in existence as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql intermediate holding companies after the Merger is consummated. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql objective of Entergy and FPL Group is to consummate the Merger by late \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In September 2000, Entergy and FPL Group announced plans to form a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql joint venture between FPL Energy and Entergy Wholesale Operations. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy and FPL Group management subsequently decided not to form a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql separate joint venture in advance of the Merger. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Selected Data \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Selected domestic utility customers and sales data for 2000 are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql summarized in the following tables: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Customers as of \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql December 31, 2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Area Served Electric Gas \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Entergy Arkansas Portions of Arkansas and Tennessee 643 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Entergy Gulf States Portions of Texas and Louisiana 681 89 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Entergy Louisiana Portions of Louisiana 641 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Entergy Mississippi Portions of Mississippi 401 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Entergy New Orleans City of New Orleans, except Algiers, which \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql is provided electric service by Entergy Louisiana 190 150 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----- --- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total customers 2,556 239 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ===== === \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 - Selected Domestic Utility Electric Energy Sales Data \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Entergy Entergy Entergy Entergy System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas Gulf States Louisiana Mississippi New Orleans Energy Entergy (a) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In GWH) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Electric Department: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales to retail \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql customers 19,333 35,475 29,680 12,847 5,880 - 103,216 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales for resale: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Affiliates 6,513 1,381 228 1,276 570 9,621 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Others 5,537 3,248 554 313 141 - 9,794 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------------------------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total 31,383 40,104 30,462 14,436 6,591 9,621 113,010 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ================================================================================== \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Average use per \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql residential customer \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (KWH) 12,449 15,861 15,436 14,629 12,784 - 14,484 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ================================================================================== \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a) Includes the effect of intercompany eliminations. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 - Selected Natural Gas Sales Data \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans and Entergy Gulf States sold 16,058,022 and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 6,472,529 MCF, respectively, of natural gas to retail customers in 2000. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the years ended December 31, 2000, 1999, and 1998, revenues from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql natural gas operations were not material for Entergy Gulf States. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans' products and services are discussed below in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql "BUSINESS SEGMENTS". \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Refer to "SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON OF ENTERGY \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql CORPORATION AND SUBSIDIARIES, ENTERGY ARKANSAS, ENTERGY GULF STATES, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY LOUISIANA, ENTERGY MISSISSIPPI, ENTERGY NEW ORLEANS, and SYSTEM \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENERGY" which follow each company's financial statements in this report, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for further information with respect to operating statistics. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Employees \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql As of December 31, 2000, Entergy had 14,100 employees as follows: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Full-time: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas 1,570 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States 1,639 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana 932 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi 889 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans 381 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Operations 3,276 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Services 2,475 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Nuclear Operations 1,609 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other subsidiaries 1,113 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------ \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total Full-time 13,884 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Part-time 216 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------ \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total Entergy 14,100 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ====== \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Approximately 4,560 employees are represented by the International \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Brotherhood of Electrical Workers Union (IBEW), the Utility Workers Union \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of America (UWUA), and the International Brotherhood of Teamsters Union \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (IBT). In 2000, both Entergy Arkansas and Entergy Mississippi reached \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql new agreements with IBEW. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Industry Restructuring and Competition \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql As a result of the actions of federal legislative and regulatory \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql bodies over the period of approximately the past twenty years, wholesale \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql markets have developed in which electricity, gas, and other energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql related products and services are purchased and sold at market-based \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (rather than traditional cost-based) rates. These wholesale markets are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql continuing to grow and evolve. This evolution has changed the ways in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql which public utilities conduct their business and has changed the nature \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the participants in these wholesale markets, which now include not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql only public utilities but also power marketers and traders, other energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commodity marketers and traders, wholesale generators of electricity, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql a wide range of wholesale customers. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Major changes in the retail utility business are now occurring in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql some parts of the United States, including some states in which Entergy's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility companies operate. Both Texas and Arkansas adopted \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql legislation in 1999 aimed at separating ("unbundling") traditionally \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql integrated public utilities into distinct distribution, transmission, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generation, and various types of retail marketing businesses, and aimed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql at introducing competition into the generation component of utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql service. The Texas legislation provides for retail open access by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql January 1, 2002. In Arkansas, retail open access has been delayed by law \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql so that it begins no sooner than October 2003 and no later than October \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2005. This delay is intended to allow further development of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql wholesale generation market, including the completion of several \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql independent generation projects within the state. Other jurisdictions in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql which the domestic utility companies operate have not enacted retail \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competition and utility unbundling legislation. Further changes in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql restructuring in Entergy's service territories, including the timing of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql implementation of restructuring and competition, may result from the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql effects of the developments in the California power supply markets. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Changes in the wholesale and retail electricity markets in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy system will take place over a number of years, and regulators and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql legislators in different jurisdictions have not coordinated these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql changes. In some cases, actions by one jurisdiction may conflict with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql actions by another, creating potentially incompatible obligations for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql public utilities and holding companies, including the Entergy system. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Examples include: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the LPSC's docket relating to the changes in corporate structure of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States as a result of complying with the Texas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql restructuring law and its potential impact on Louisiana retail \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ratepayers (described more fully in Note 2 to the financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements); and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o System Agreement restructuring issues (described more fully in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - SIGNIFICANT \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FACTORS AND KNOWN TRENDS - Federal Regulatory and Legislative \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Activity - Proposed System Agreement Amendments"). \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql It is too early to accurately predict how incompatible obligations will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql be resolved or the effects of the changes that are taking place in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql wholesale and retail energy markets. However, these changes will result \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in fundamental alterations in the way traditional integrated utilities \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and holding company systems, like Entergy and its domestic utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies, conduct their business. Some of these alterations will be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql positive for Entergy and its affiliates, while others will not be. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql These changes are resulting in increased costs associated with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility unbundling and transitioning to new organizational structures and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ways of conducting business. It is possible that the new organizational \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql structures that will be required will result in lost economies of scale, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql less beneficial cost sharing arrangements within utility holding company \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql systems, and, in some cases, greater difficulty and cost in accessing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql capital. Furthermore, these changes could result in early refinancing of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql debt, the reorganization of debt, or other obligations between newly- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql formed companies. Ultimately, capital structures may result that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql initially are more complex than the existing capital structures of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility companies. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Utilities, including the domestic utility companies, may be required \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql or encouraged to sell generating plants or interests therein, or the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql output from such plants. FERC set December 15, 2001 as the date by which \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql all owners and operators of transmission lines should sell or turn over \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operating and management responsibility for their transmission systems to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql independent parties. Entergy has responded to FERC by filing plans to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transfer control of its transmission assets to a non-affiliated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmission company subject to control by a regional transmission \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql organization. These changes will alter the historical structure from the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operation of the domestic utility companies' electric generation and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmission assets as an integrated system supporting utility service \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql throughout their combined service territories. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql As a potential result of restructuring, Entergy's domestic utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies may no longer be able to apply regulated utility accounting \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql principles to some or all of their operations, and they may be required \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to write off certain regulatory assets or recognize asset impairments. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql There are a number of other changes that may result from electric \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql industry competition and unbundling, including but not limited to changes \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in labor relations, management and staffing, structure of operations, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql environmental compliance responsibility, and other aspects of the utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql business. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - SIGNIFICANT \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FACTORS AND KNOWN TRENDS" and Note 2 to the financial statements contain \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql detailed discussions of the competitive challenges Entergy faces in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility industry, including the status of the transition to a more \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competitive utility business environment for the domestic utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql CAPITAL REQUIREMENTS AND FUTURE FINANCING \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the years 2001 through 2003, Entergy plans to spend $8.2 billion \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in a capital investment plan focused on improving service at the domestic \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility companies and growing the global power development and domestic \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql non-utility nuclear businesses. It is estimated that $2.6 billion will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql be spent by the domestic utility companies, $3.6 billion by the global \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power development business, and $2.0 billion by the domestic non-utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql nuclear business. The capital investment plan is subject to modification \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql based on the ongoing effects of transition to competition planning, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ability to recover regulated utility costs in rates, and the proposed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql business combination with FPL Group. Additionally, the plan is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contingent upon the ability to access the capital necessary to finance \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the planned expenditures, and significant borrowings may be necessary to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql implement these capital spending plans. Capital expenditures (including \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql nuclear fuel but excluding AFUDC) for Entergy are estimated at $3.2 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql billion in 2001, $2.5 billion in 2002, and $2.6 billion in 2003. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Included in these totals are estimated construction expenditures for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility companies and System Energy as follows: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2001 2002 2003 Total \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Millions) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas $297 $200 $205 $702 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States $293 $216 $220 $729 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana $222 $175 $168 $565 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi $147 $128 $113 $388 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans $53 $46 $48 $147 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy $41 $14 $12 $67 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The domestic utility companies will mainly focus their planned \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql spending on distribution and transmission projects that will support \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql continued reliability improvements and transitioning to a more \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competitive environment. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The global power development business will mainly focus its planned \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql spending on several merchant power plant projects either under \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql construction or in the planning stages in the U.S. and Europe, including \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the purchase of gas turbines scheduled for delivery in 2001 through 2004 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql under an option to purchase obtained from GE Power Systems. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The domestic non-utility nuclear business will mainly focus its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql planned spending on the acquisition of U.S. nuclear power plants from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql other utilities, including the anticipated purchase in 2001, pending \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulatory approvals, of IP2. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation's primary capital requirements are to invest \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql periodically in, or make loans to, its subsidiaries and to invest in new \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql enterprises. In February 2001, Entergy Corporation made a cash \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contribution consisting of equity investment and loans of approximately \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $414 million in the formation of Entergy-Koch, L.P. Entergy Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql also requires capital for its stock repurchase plans. In addition to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql meeting capital expenditure requirements, Entergy must meet scheduled \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql long-term debt and preferred stock maturities and cash sinking fund \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql requirements. Actual capital expenditures may vary from the estimates \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql given for a number of reasons, including changes in load growth \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql estimates; environmental regulations; labor, equipment, materials, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql capital costs; modifications to generating units to meet regulatory \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql requirements; the transition to competition; and the proposed business \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql combination with FPL Group. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management more thoroughly discusses Entergy's capital investment and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql common stock repurchase plans, financing requirements, Entergy Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql credit support requirements, and its sources and uses of capital in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - LIQUIDITY AND CAPITAL \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESOURCES" and Notes 4, 5, 6, 7, 9, and 10 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Certain Grand Gulf-related Financial and Support Agreements \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, Entergy New Orleans, and System Energy) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The Unit Power Sales Agreement allocates capacity, energy, and the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql related costs from System Energy's 90% ownership and leasehold interests \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in Grand Gulf 1 to Entergy Arkansas (36%), Entergy Louisiana (14%), \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi (33%), and Entergy New Orleans (17%). Each of these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies is obligated to make payments to System Energy for its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql entitlement of capacity and energy on a full cost-of-service basis \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regardless of the quantity of energy delivered, so long as Grand Gulf 1 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql remains in commercial operation. Payments under the Unit Power Sales \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement are System Energy's only source of operating revenues. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial condition of System Energy depends upon the continued \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commercial operation of Grand Gulf 1 and the receipt of such payments. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans generally recover payments made under the Unit Power Sales \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement through the rates charged to their customers. In the case of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas and Entergy Louisiana, payments are also recovered \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql through sales of electricity from their respective retained shares of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Grand Gulf 1. The retained shares are discussed in Note 2 to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial statements under the heading "Grand Gulf 1 Deferrals and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retained Shares." \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, Entergy New Orleans, and System Energy) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The Availability Agreement among System Energy and Entergy Arkansas, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql entered into in 1974 in connection with the financing by System Energy of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Grand Gulf. The Availability Agreement provided that System Energy would \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql join in the System Agreement on or before the date on which Grand Gulf 1 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql was placed in commercial operation and would make available to Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql all capacity and energy available from System Energy's share of Grand \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans also agreed severally to pay System Energy monthly \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for the right to receive capacity and energy from Grand Gulf in amounts \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that (when added to any amounts received by System Energy under the Unit \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Power Sales Agreement, or otherwise) would at least equal System Energy's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql total operating expenses for Grand Gulf (including depreciation at a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql specified rate) and interest charges. The September 1989 write-off of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy's investment in Grand Gulf 2, amounting to approximately \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $900 million, is being amortized for Availability Agreement purposes over \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 27 years. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The allocation percentages under the Availability Agreement are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fixed as follows: Entergy Arkansas - 17.1%; Entergy Louisiana - 26.9%; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi - 31.3%; and Entergy New Orleans - 24.7%. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql allocation percentages under the Availability Agreement would remain in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql effect and would govern payments made under such agreement in the event \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of a shortfall of funds available to System Energy from other sources, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql including payments under the Unit Power Sales Agreement. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy has assigned its rights to payments and advances from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans under the Availability Agreement as security for its first \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql mortgage bonds and reimbursement obligations to certain banks providing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the letters of credit in connection with the equity funding of the sale \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and leaseback transactions described in Note 10 to the financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements under "Sale and Leaseback Transactions - Grand Gulf 1 Lease \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Obligations." In these assignments, Entergy Arkansas, Entergy Louisiana, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi, and Entergy New Orleans further agreed that, in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql event they were prohibited by governmental action from making payments \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql under the Availability Agreement (for example, if FERC reduced or \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql disallowed such payments as constituting excessive rates), they would \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql then make subordinated advances to System Energy in the same amounts and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql at the same times as the prohibited payments. System Energy would not be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql allowed to repay these subordinated advances so long as it remained in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql default under the related indebtedness or in other similar circumstances. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Each of the assignment agreements relating to the Availability \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement provides that Entergy Arkansas, Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, and Entergy New Orleans will make payments directly to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy. However, if there is an event of default, those payments \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql must be made directly to the holders of indebtedness that are the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql beneficiaries of such assignment agreements. The payments must be made \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql pro rata according to the amount of the respective obligations secured. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The obligations of Entergy Arkansas, Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, and Entergy New Orleans to make payments under the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Availability Agreement are subject to the receipt and continued \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql effectiveness of all necessary regulatory approvals. Sales of capacity \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and energy under the Availability Agreement would require that the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Availability Agreement be submitted to FERC for approval with respect to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the terms of such sale. No such filing with FERC has been made because \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql sales of capacity and energy from Grand Gulf are being made pursuant to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Unit Power Sales Agreement. If, for any reason, sales of capacity \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and energy are made in the future pursuant to the Availability Agreement, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the jurisdictional portions of the Availability Agreement would be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql submitted to FERC for approval. Other aspects of the Availability \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement are subject to the jurisdiction of the SEC, whose approval has \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql been obtained, under PUHCA. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Since commercial operation of Grand Gulf 1 began, payments under the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Unit Power Sales Agreement to System Energy have exceeded the amounts \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql payable under the Availability Agreement. Therefore, no payments under \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Availability Agreement have ever been required. If Entergy Arkansas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql or Entergy Mississippi fails to make its Unit Power Sales Agreement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql payments, and System Energy is unable to obtain funds from other sources, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana and Entergy New Orleans could become subject to claims \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql or demands by System Energy or its creditors for payments or advances \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql under the Availability Agreement (or the assignments thereof) equal to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the difference between their required Unit Power Sales Agreement payments \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and their required Availability Agreement payments. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The Availability Agreement may be terminated, amended, or modified \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by mutual agreement of the parties thereto, without further consent of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql any assignees or other creditors. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Capital Funds Agreement (Entergy Corporation and System Energy) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy and Entergy Corporation have entered into the Capital \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Funds Agreement, whereby Entergy Corporation has agreed to supply System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Energy with sufficient capital to (i) maintain System Energy's equity \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql capital at an amount equal to a minimum of 35% of its total \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql capitalization (excluding short-term debt) and (ii) permit the continued \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commercial operation of Grand Gulf 1 and pay in full all indebtedness for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql borrowed money of System Energy when due. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation has entered into various supplements to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Capital Funds Agreement. System Energy has assigned its rights under \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql such supplements as security for its first mortgage bonds and for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reimbursement obligations to certain banks providing letters of credit in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql connection with the equity funding of the sale and leaseback transactions \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql described in Note 10 under "Sale and Leaseback Transactions - Grand Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1 Lease Obligations." Each such supplement provides that permitted \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql indebtedness for borrowed money incurred by System Energy in connection \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with the financing of Grand Gulf may be secured by System Energy's rights \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql under the Capital Funds Agreement on a pro rata basis (except for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Specific Payments, as defined below). In addition, in the supplements to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Capital Funds Agreement relating to the specific indebtedness being \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql secured, Entergy Corporation has agreed to make cash capital \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contributions directly to System Energy sufficient to enable System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Energy to make payments when due on such indebtedness (Specific \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Payments). However, if there is an event of default, Entergy Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql must make those payments directly to the holders of indebtedness \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql benefiting from the supplemental agreements. The payments (other than \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Specific Payments) must be made pro rata according to the amount of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the respective obligations benefiting from the supplemental agreements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The Capital Funds Agreement may be terminated, amended, or modified \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by mutual agreement of the parties thereto, upon obtaining the consent, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql if required, of those holders of System Energy's indebtedness then \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql outstanding who have received the assignments of the Capital Funds \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RATE MATTERS AND REGULATION \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Rate Matters \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The retail rates of Entergy's domestic utility companies are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulated by state or local regulatory authorities, as described below. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FERC regulates their wholesale rates (including intrasystem sales \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql pursuant to the System Agreement) and interstate transmission of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql electricity, as well as rates for System Energy's sales of capacity and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql energy from Grand Gulf 1 to Entergy Arkansas, Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, and Entergy New Orleans pursuant to the Unit Power Sales \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Wholesale Rate Matters \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql As described above under "CAPITAL REQUIREMENTS AND FUTURE FINANCING \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql - Certain Grand Gulf-related Financial and Support Agreements," System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Energy recovers costs related to its interest in Grand Gulf 1 through \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rates charged to Entergy Arkansas, Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, and Entergy New Orleans for capacity and energy under the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Unit Power Sales Agreement. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In December 1995, System Energy implemented a $65.5 million rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increase, subject to refund. In 1998, FERC approved requests by Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas and Entergy Mississippi to accelerate a portion of their Grand \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf purchased power obligations. The rate increase request filed by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy with FERC and the Grand Gulf accelerated recovery tariffs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql are discussed in Note 2 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Agreement (Entergy Corporation, Entergy Arkansas, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The domestic utility companies have historically engaged in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql coordinated planning, construction, and operation of generation and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmission facilities pursuant to the terms of the System Agreement, as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql described under "PROPERTY - Generating Stations," below. Restructuring \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in the electric utility industry will affect these coordinated activities \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in the future. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The LPSC and the Council commenced a proceeding at FERC in April \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 that requests revisions to the System Agreement that the LPSC and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Council allege are necessary to accommodate the introduction of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql retail competition in Texas and Arkansas. In June 2000, Entergy's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility companies filed proposed amendments to the System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement with FERC to facilitate the implementation of retail \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competition in Arkansas and Texas and to provide for continued \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql equalization of costs among the domestic utilities in Louisiana and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi. The LPSC and the Council's complaint and Entergy's proposed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amendments are more thoroughly discussed in "MANAGEMENT'S FINANCIAL \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql DISCUSSION AND ANALYSIS - SIGNIFICANT FACTORS AND KNOWN TRENDS". These \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql proceedings have been consolidated with a previous complaint filed with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FERC by the LPSC in 1995. In that complaint, the LPSC requested, among \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql other things, modification of the System Agreement to exclude curtailable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql load from the cost allocation determination. Hearings in these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql proceedings have been scheduled for March 2001, with an initial ALJ \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decision expected by June 2001. Entergy requested a final decision from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FERC by October 2001, however, neither the timing, nor the ultimate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql outcome, of the proceeding can be predicted at this time. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Open Access Transmission (Entergy Corporation, Entergy Arkansas, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States, Entergy Louisiana, Entergy Mississippi, and Entergy New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FERC issued Order 2000 in December 1999, which calls for owners and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operators of transmission lines in the United States to join regional \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmission organizations (RTOs) on a voluntary basis. Order 2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql requires that RTOs commence independent operations no later than December \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 15, 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql It appears that FERC will be flexible regarding the structure of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RTOs. For example, it appears that RTOs may be for-profit or not-for- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql profit and may be organized as joint ventures or legal entities of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql various other types. However, RTOs will be required, among other things, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to be independent of market participants, to have sufficient regional \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql scope to maintain reliability and efficiency, to be non-discriminatory in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql granting service, and to maintain operational control over their regional \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmission systems. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In October 2000, in compliance with Order 2000, Entergy made a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql filing with FERC that requested: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o authorization to establish an RTO referred to as Transco; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o authorization to transfer the domestic utility companies' \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmission assets to the Transco; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a determination that the partnership arrangement with the Southwest \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Power Pool (SPP) that the Transco proposes to operate in would qualify \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql as an independent RTO. The partnership arrangement provides for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operations under the oversight of, and within, the SPP RTO. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The amounts of the domestic utility companies' net transmission utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql plant assets recorded in their financial statements are provided in Note \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1 to the financial statements under the heading "Utility Plant." \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The proposed Transco will be a limited liability company. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql managing member of the Transco will be a separate corporation with a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql board of directors independent of Entergy. The Transco will be: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o regulated by FERC; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o composed of the transmission system transferred to it by the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility companies and other transmission owners in Entergy's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql current service territory region; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o operated and maintained by employees who would work exclusively for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Transco and would not be employed by Entergy or the domestic utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o passively owned by the domestic utility companies and other member \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies who will transfer assets but not control or otherwise direct \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql its operation and management. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy filed in December 2000 for FERC approval of the rates for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmission service across Transco's facilities. Included in this rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql filing is a request to cancel Service Schedule MSS-2, the portion of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Agreement related to equalization of certain transmission costs. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In March 2001, Entergy, Entergy Services, and the domestic utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies requested SEC approval under PUHCA of certain elements of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Transco plan. The domestic utility companies have also made filings with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql their local regulators for Transco approval. Under its planned timeline, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy expects to have the necessary regulatory approvals by the third \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql quarter of 2001, with the transmission asset transfers occurring before \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Transco commences independent operations in December 2001. In the event \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that some or all of these transmission assets cannot be transferred to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Transco by December 2001, operational control of these assets will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql move to an intermediate entity as of that date. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retail Rate Regulation \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql General (Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi, and Entergy New Orleans) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Certain costs related to Grand Gulf 1, Waterford 3, and River Bend \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql were phased into retail rates over a period of years in order to avoid \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the "rate shock" associated with increasing rates to reflect all such \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs at once. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and the portion of Entergy Gulf States regulated by the LPSC have fully \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovered such deferred costs associated with one or more of the plants. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans' phase-in plan will be completed in 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The retail regulatory philosophy has shifted in some jurisdictions \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql from traditional, exclusively cost-of-service regulation to include \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql performance-based rate elements. Performance-based formula rate plans \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql are designed to encourage efficiencies and productivity while permitting \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utilities and their customers to share in the benefits. Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi and Entergy Louisiana have implemented performance-based \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql formula rate plans. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The domestic utility companies have initiated proceedings with state \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and local regulators regarding transition to a more competitive market \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for electricity. In addition, retail open access laws have been enacted \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in Arkansas and Texas. These matters are discussed more thoroughly in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Note 2 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retail Rate Proceedings \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas' material retail rate proceedings that were \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql resolved during the past year, are currently pending, or affect current \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql year results are discussed in Note 2 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Recovery of Grand Gulf 1 Costs \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Under the settlement agreement entered into with the APSC in 1985 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and amended in 1988, Entergy Arkansas retains 22% of its share of Grand \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf 1 costs and recovers the remaining 78% of its share through rates. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Under the Unit Power Sales Agreement, Entergy Arkansas' share of Grand \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf 1 costs is 36%. In the event Entergy Arkansas is not able to sell \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql its retained share to third parties, it may sell such energy to its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql retail customers at a price equal to its avoided energy cost, which is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql currently less than Entergy Arkansas' cost of energy from the retained \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql share. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel Recovery \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas' rate schedules include an energy cost recovery \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rider to recover fuel and purchased energy costs in monthly bills. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rider utilizes projected energy costs for the twelve month period \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commencing on April 1 of each year to develop an energy cost rate, which \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql is redetermined annually and includes a true-up adjustment reflecting the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql over-recovery or under-recovery, including carrying charges, of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql energy cost for the prior calendar year. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Rate Freeze \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In December 1997, the APSC approved a settlement agreement resolving \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas' transition to competition case. One provision in that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql settlement was that base rates would remain at the level resulting from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that case until at least July 1, 2001. The terms of the settlement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql agreement are discussed in Note 2 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retail Rate Proceedings \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States' material retail rate proceedings that were \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql resolved during the past year, are currently pending, or affect current \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql year results are discussed in Note 2 to the financial statements. In \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql addition, the 1999 settlement agreement that resolved Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States' 1996 and 1998 rate proceedings, which is currently under appeal, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and various other matters are discussed in Note 2 to the financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Texas Jurisdiction - River Bend \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In March 1998, the PUCT issued an order disallowing recovery of $1.4 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql billion of company-wide abeyed River Bend plant costs which have been \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql held in abeyance since 1988. Entergy Gulf States has appealed the PUCT's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decision on this matter to a Texas District Court. The 1999 settlement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql agreement mentioned above addresses the treatment of abeyed plant costs, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and, as a result, Entergy Gulf States removed the reserve for these costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and reduced the plant asset in 1999. Based on advice of counsel, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql management believes that it is probable that the matter will be remanded \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql again to the PUCT for a further ruling on the prudence of the abeyed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql plant costs and it is reasonably possible that some portion of these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs will be added to the net book value of the River Bend plant for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulatory purposes. The abeyed plant costs are discussed in more detail \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in Note 2 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel Recovery \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States' Texas rate schedules include a fixed fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql factor to recover fuel and purchased power costs, including carrying \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql charges, not recovered in base rates. The 1999 settlement agreement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql mentioned above established a methodology for semi-annual revisions of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the fixed fuel factor in March and September based on the market price of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql natural gas. This agreement is effective through December 2001 or until \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql otherwise ordered by the PUCT. To the extent actual costs vary from the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fixed fuel factor, refunds or surcharges are required or permitted. Fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs are also subject to reconciliation proceedings. In connection with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the implementation of restructuring in Texas, Entergy Gulf States \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql anticipates that it will file a final fuel reconciliation in March 2003 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for the period ending December 31, 2001. Beginning in January 2002, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql which is the scheduled start of retail open access in Texas, fuel and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchased power cost recovery will be subject to the PUCT's rule \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql governing the price that Entergy Gulf States' affiliated retail electric \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql provider may charge residential and commercial customers, as discussed in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql more detail in Note 2 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States' Louisiana electric rate schedules include a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel adjustment clause designed to recover the cost of fuel and purchased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power costs in the second prior month, adjusted by a surcharge or credit \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for deferred fuel expense and related carrying charges arising from the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql monthly reconciliation of actual fuel costs incurred with fuel revenues \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql billed to customers. The LPSC and the PUCT fuel cost reviews that were \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql resolved during the past year or are currently pending are discussed in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Note 2 to the financial statements. In July 2000, the LPSC issued an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql order requiring Entergy Gulf States to realign approximately $2.4 million \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of certain Louisiana fuel costs from the fuel adjustment clause to base \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rates. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States' Louisiana gas rates include a purchased gas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adjustment based on estimated gas costs for the billing month adjusted by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql a surcharge or credit for deferred fuel expense arising from the monthly \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reconciliation of actual fuel costs incurred with fuel cost revenues \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql billed to customers. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retail Rate Proceedings \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana's material retail rate proceedings that were \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql resolved during the past year, are currently pending, or affect current \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql year results are discussed in Note 2 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Recovery of Grand Gulf 1 Costs \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In a series of LPSC orders, court decisions, and agreements from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql late 1985 to mid-1988, Entergy Louisiana was granted rate relief with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql respect to costs associated with Entergy Louisiana's share of capacity \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and energy from Grand Gulf 1, subject to certain terms and conditions. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In November 1988, Entergy Louisiana agreed to retain 18% of its share of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Grand Gulf 1 costs and recover the remaining 82% of its share through \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rates. Under the Unit Power Sales Agreement, Entergy Louisiana's share \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Grand Gulf 1 costs is 14%. Non-fuel operation and maintenance costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for Grand Gulf 1 are recovered through Entergy Louisiana's base rates. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Additionally, Entergy Louisiana is allowed to recover, through the fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adjustment clause, 4.6 cents per KWH for the energy related to its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql retained portion of these costs. Alternatively, Entergy Louisiana may \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql sell such energy to nonaffiliated parties at prices above the fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adjustment clause recovery amount, subject to the LPSC's approval. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Performance-Based Formula Rate Plan \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana files a performance-based formula rate plan by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql April 15 of each year that compares the annual rate of return on common \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql equity (ROE) with a benchmark ROE. The benchmark ROE determined under \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the formula rate plan includes the current approved ROE adjusted for a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql customer satisfaction performance measure. The formula rate plan allows \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for periodic adjustments in retail rates if the annually determined ROE \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql is outside an allowed range of the benchmark ROE. The performance-based \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql formula rate plan will end in 2001 after the filing for the 2000 test \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql year unless a continuance is ordered. Entergy Louisiana's performance- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql based formula rate plan filings are discussed in Note 2 to the financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel Recovery \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana's rate schedules include a fuel adjustment clause \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql designed to recover the cost of fuel in the second prior month, adjusted \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by a surcharge or credit for deferred fuel expense and related carrying \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql charges arising from the monthly reconciliation of actual fuel costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql incurred with fuel cost revenues billed to customers. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retail Rate Proceedings \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi's material retail rate proceedings that were \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql resolved during the past year, are currently pending, or affect current \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql year results are discussed in Note 2 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Performance-Based Formula Rate Plan \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi files a performance-based formula rate plan \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql every 12 months that compares the annual earned rate of return to and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adjusts it against a benchmark rate of return. The benchmark is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql calculated under a separate formula within the formula rate plan. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql formula rate plan allows for periodic small adjustments in rates based on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql a comparison of actual earned returns to benchmark returns and upon \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql certain performance factors. The formula rate plan filing for the 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql test year is discussed in Note 2 to the financial statements. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql formula rate plan filing for the 2000 test year will be submitted in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql March 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel Recovery \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi's rate schedules include an energy cost recovery \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rider to recover fuel and purchased energy costs. In December 2000, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MPSC approved the recovery of $136.7 million of under-recoveries, plus \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql carrying charges, over a 24-month period effective with the first billing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cycle of January 2001. Effective with January 2001 billings, the rider \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utilizes projected energy costs filed quarterly by Entergy Mississippi to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql develop an energy cost rate. The energy cost rate is redetermined each \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql calendar quarter and includes a true-up adjustment reflecting the over- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovery or under-recovery of the energy cost as of the second quarter \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql preceding the redetermination. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retail Rate Proceedings \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans' material retail rate proceedings that were \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql resolved during the past year, are currently pending, or affect current \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql year results are discussed in Note 2 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Recovery of Grand Gulf 1 Costs \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Under Entergy New Orleans' various rate settlements with the Council \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in 1986, 1988, and 1991, Entergy New Orleans agreed to absorb and not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recover from ratepayers a total of $96.2 million of its Grand Gulf 1 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs. Entergy New Orleans was permitted to implement annual rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increases in decreasing amounts each year through 1995, and to defer \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql certain costs and related carrying charges for recovery on a schedule \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql extending from 1991 through 2001. As of December 31, 2000, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql uncollected balance of Entergy New Orleans' deferred costs was $11 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel Recovery \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans' electric rate schedules include a fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adjustment clause designed to recover the cost of fuel in the second \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql prior month, adjusted by a surcharge or credit for deferred fuel expense \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql arising from the monthly reconciliation of actual fuel costs incurred \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with fuel cost revenues billed to customers. The adjustment also \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql includes the difference between non-fuel Grand Gulf 1 costs paid by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans and the estimate of such costs, which are included in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql base rates, as provided in Entergy New Orleans' Grand Gulf 1 rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql settlements. Entergy New Orleans' gas rate schedules include an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adjustment to reflect estimated gas costs for the billing month, adjusted \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by a surcharge or credit similar to that included in the electric fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adjustment clause, in addition to carrying charges. The Council is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql currently studying Entergy New Orleans' fuel adjustment methodologies, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with the intention of considering means of mitigating the effect on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ratepayers of sudden increases in fuel costs. The resolution commencing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the study notes that the Council does not intend to deny Entergy New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans full recovery of its prudently incurred fuel and purchased power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Regulation \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Federal Regulation (Entergy Corporation, Entergy Arkansas, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PUHCA \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation and its various direct and indirect subsidiaries \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql are subject to the broad regulatory provisions of PUHCA, with the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql exception of its EWG and FUCO subsidiaries. Except with respect to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql investments in EWGs and FUCOs, the principal regulatory provisions of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PUHCA: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o limit the operations of a registered holding company system to a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql single, integrated public utility system, plus certain ancillary and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql related systems and businesses; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o regulate certain transactions among affiliates within a holding \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql company system; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o govern the issuance, acquisition, and disposition of securities and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql assets by registered holding companies and their subsidiaries; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o limit the entry by registered holding companies and their \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql subsidiaries into businesses other than electric and/or gas utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql businesses; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o require SEC approval for certain utility mergers and acquisitions, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql including Entergy's proposed merger with FPL Group. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation and other electric utility holding companies \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql have supported legislation in the United States Congress to repeal PUHCA \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and transfer certain aspects of the oversight of public utility holding \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies from the SEC to FERC. Entergy believes that PUHCA inhibits its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ability to compete in the evolving electric energy marketplace and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql largely duplicates the oversight activities otherwise performed by FERC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and other federal regulators and by state and local regulators. In June \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1995, the SEC adopted a report proposing options for the repeal or \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql significant modification of PUHCA, but the U.S. Congress has not passed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql legislation pursuant to this report. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Federal Power Act \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The domestic utility companies, System Energy, Entergy Power, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql EPMC are subject to the Federal Power Act as administered by FERC and the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql DOE. The Federal Power Act provides for regulatory jurisdiction over the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmission and wholesale sale of electric energy in interstate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commerce, licensing of certain hydroelectric projects and certain other \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql activities, including accounting policies and practices. Such regulation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql includes jurisdiction over the rates charged by System Energy for Grand \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf 1 capacity and energy provided to Entergy Arkansas, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana, Entergy Mississippi, and Entergy New Orleans. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas holds a FERC license for two hydroelectric projects \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql totaling 70 MW of capacity that was renewed on July 2, 1980 and expires \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql on February 28, 2003. In December 2000, Entergy Arkansas filed a license \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql extension application with FERC for these two facilities. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Regulation of the Nuclear Power Industry (Entergy Corporation, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas, Entergy Gulf States, Entergy Louisiana, and System Energy) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Regulation of Nuclear Power \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Under the Atomic Energy Act of 1954 and the Energy Reorganization \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Act of 1974, the operation of nuclear plants is heavily regulated by the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql NRC, which has broad power to impose licensing and safety-related \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql requirements. In the event of non-compliance, the NRC has the authority \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to impose fines or shut down a unit, or both, depending upon its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql assessment of the severity of the situation, until compliance is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql achieved. Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy, as owners of all or portions of ANO, River Bend, Waterford \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 3, and Grand Gulf 1, respectively, and Entergy Operations, as the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql licensee and operator of these units, are subject to the jurisdiction of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the NRC. Additionally, Entergy's domestic non-utility nuclear business \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql is subject to the NRC's jurisdiction as the owner and operator of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Pilgrim, Indian Point 3 and FitzPatrick. Revised safety requirements \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql promulgated by the NRC have, in the past, necessitated substantial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql capital expenditures at these nuclear plants, and additional expenditures \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql could be required in the future. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The nuclear power industry faces uncertainties with respect to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cost and long-term availability of sites for disposal of spent nuclear \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel and other radioactive waste, nuclear plant operations, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql technological and financial aspects of decommissioning plants at the end \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of their licensed lives, and requirements relating to nuclear insurance. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql These matters are briefly discussed below. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Regulation of Spent Fuel and Other High-Level Radioactive Waste \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Under the Nuclear Waste Policy Act of 1982, the DOE is required, for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql a specified fee, to construct storage facilities for, and to dispose of, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql all spent nuclear fuel and other high-level radioactive waste generated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by domestic nuclear power reactors. However, the DOE has not yet \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql identified a permanent storage repository and, as a result, future \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expenditures may be required to increase spent fuel storage capacity at \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's nuclear plant sites. Information concerning spent fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql disposal contracts with the DOE, current on-site storage capacity, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs of providing additional on-site storage is presented in Note 9 to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Regulation of Low-Level Radioactive Waste \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The availability and cost of disposal facilities for low-level \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql radioactive waste resulting from normal nuclear plant operations are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql subject to a number of uncertainties. Under the Low-Level Radioactive \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Waste Policy Act of 1980, as amended, each state is responsible for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql disposal of waste originating in that state, but states may participate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in regional compacts to fulfill their responsibilities jointly. Arkansas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and Louisiana participate in the Central Interstate Low-Level Radioactive \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Waste Compact (Central States Compact), and Mississippi participates in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Southeast Low-Level Radioactive Waste Compact (Southeast Compact). \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Both the Central States Compact and the Southeast Compact waste facility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql development projects are on hold and further development efforts are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql unknown at this time. Neither Massachusetts, where Pilgrim is located, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql nor New York, where Indian Point 3 and FitzPatrick are located, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql participates in any regional compact and efforts to fulfill their \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql responsibilities have been minimal. Two licensed disposal sites are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql currently operating in the United States, but only one site, the Barnwell \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Disposal Facility (Barnwell) located in South Carolina, is open to out-of- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql region generators. The availability of Barnwell provides only a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql temporary solution for Entergy's low-level radioactive waste storage and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql does not alleviate the need to develop new disposal capacity. In June \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, the governor of South Carolina signed legislation forming a new low- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql level waste compact with the states of Connecticut and New Jersey. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql compact will start restricting acceptance of out-of-region waste in 2002 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and totally ban out-of-region waste by 2008. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The Southeast Compact has filed sanctions against the host state of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql North Carolina and the process is currently on hold pending resolution of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the sanctions action by the compact. In December 1998, the host state \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for the Central States Compact, Nebraska, denied the compact's license \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql application. In December 1998, Entergy and two other utilities in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Central States Compact filed a lawsuit against the state of Nebraska \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql seeking damages resulting from delays and a faulty license review \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql process. Entergy Arkansas, Entergy Louisiana, and Entergy Gulf States, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql along with other waste generators, fund the development costs for new \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql disposal facilities relating to the Central States Compact. Development \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs to be incurred in the future are difficult to predict. The current \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql schedules for the site development in both the Central States Compact and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Southeast Compact are undetermined at this time. Until long-term \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql disposal facilities are established, Entergy will seek continued access \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to existing facilities. If such access is unavailable, Entergy will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql store low-level waste at its nuclear plant sites. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Regulation of Nuclear Plant Decommissioning \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, and System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Energy are recovering through electric rates the estimated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decommissioning costs for ANO, River Bend, Waterford 3, and Grand Gulf 1, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql respectively. These amounts are deposited in trust funds which, together \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with the related earnings, can only be used for future decommissioning \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs. Estimated decommissioning costs are periodically reviewed and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql updated to reflect inflation and changes in regulatory requirements and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql technology. Applications are periodically made to appropriate regulatory \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql authorities to reflect, in rates, the changes in projected \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decommissioning costs. In conjunction with the Pilgrim acquisition, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy received Pilgrim's decommissioning trust fund. Based on cost \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql estimates provided by an outside consultant, Entergy believes that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Pilgrim's decommissioning fund will be adequate to cover future \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decommissioning costs for the plant without any additional deposits to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the trust. Subject to decommissioning service agreements between Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and NYPA, NYPA retains the decommissioning liability and trusts relating \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to Indian Point 3 and FitzPatrick up to a specified amount. Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql believes that the amounts that will be available from the trusts will be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql sufficient to cover the future decommissioning costs of Indian Point 3 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and FitzPatrick without any additional contributions to the trusts. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Additional information with respect to decommissioning costs for ANO, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql River Bend, Waterford 3, Grand Gulf 1, Pilgrim, Indian Point 3, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FitzPatrick is found in Note 9 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The EPAct requires all electric utilities (including Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas, Entergy Gulf States, Entergy Louisiana, and System Energy) that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchased uranium enrichment services from the DOE to contribute up to a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql total of $150 million annually over approximately 15 years (adjusted for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql inflation, up to a total of $2.25 billion) for decontamination and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decommissioning of enrichment facilities. In accordance with the EPAct, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contributions to decontamination and decommissioning funds are recovered \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql through rates in the same manner as other fuel costs. The estimated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql annual contributions by Entergy for decontamination and decommissioning \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fees are discussed in Note 9 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nuclear Insurance \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The Price-Anderson Act limits public liability for a single nuclear \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql incident to approximately $9.5 billion. Entergy Arkansas, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States, Entergy Louisiana, System Energy, and Entergy's domestic non- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility nuclear business have protection with respect to this liability \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql through a combination of private insurance and an industry assessment \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql program, as well as insurance for property damage, costs of replacement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power, and other risks relating to nuclear generating units. Insurance \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql applicable to the nuclear programs of Entergy is discussed in Note 9 to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nuclear Operations \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql General (Entergy Corporation, Entergy Arkansas, Entergy Gulf States, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana, and System Energy) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Operations operates ANO, River Bend, Waterford 3, and Grand \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf 1, subject to the owner oversight of Entergy Arkansas, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States, Entergy Louisiana, and System Energy, respectively. Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas, Entergy Gulf States, Entergy Louisiana, and System Energy pay \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql directly or reimburse Entergy Operations at cost for its operation of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql nuclear units. Entergy's domestic non-utility nuclear business is the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operator of Pilgrim, Indian Point 3 and FitzPatrick. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ANO Matters (Entergy Corporation and Entergy Arkansas) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cracks in steam generator tubes at ANO 2 were discovered and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql repaired during an outage in March 1992. Further inspections and repairs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql were conducted during subsequent refueling and mid-cycle outages and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql turbine modifications were installed in May 1997 to restore most of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql output lost due to steam generator fouling and tube plugging. In October \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1996, the Board authorized Entergy Arkansas and Entergy Operations to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fabricate and install replacement steam generators at ANO 2. Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operations thereafter entered into contracts for the design, fabrication, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and installation of replacement steam generators. In December 1998, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql APSC issued an order finding replacement of the ANO 2 steam generators to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql be in the public interest. The steam generators were replaced during a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql refueling outage in the second half of 2000. During the next scheduled \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql outage, an examination of both generators is planned to evaluate their \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql wear and to meet the requirements of industry guidelines for steam \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generator program integrity. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In February 2000, Entergy Operations applied to the NRC for an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql extension of ANO 1's operating license. The current license expires in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2014, and, if granted, the extension would provide the authority to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql continue operating ANO 1 until 2034. Management expects the NRC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql consideration process to take two years. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In December 2000, Entergy Operations applied to the NRC for an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amendment to ANO 2's operating license that would allow for an increase \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in the reactor core power rating. If granted, this amendment will allow \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ANO 2 to increase its gross electrical output by approximately 90 MW. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Operations has requested action by the NRC on the amendment by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql March 2002, to permit implementation of the uprate following ANO 2's next \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql scheduled refueling outage. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql State Regulation (Entergy Arkansas, Entergy Gulf States, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana, Entergy Mississippi, and Entergy New Orleans) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql General \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas is subject to regulation by the APSC, which \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql includes the authority to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o oversee utility service; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o set rates; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o determine reasonable and adequate service; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o require proper accounting; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o control leasing; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o control the acquisition or sale of any public utility plant or \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql property constituting an operating unit or system; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o set rates of depreciation; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o issue certificates of convenience and necessity and certificates of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql environmental compatibility and public need; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o regulate the issuance and sale of certain securities. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States is subject to the jurisdiction of the municipal \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql authorities of a number of incorporated cities in Texas as to retail \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rates and service within their boundaries, with appellate jurisdiction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql over such matters residing in the PUCT. Entergy Gulf States' Texas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql business is also subject to regulation by the PUCT as to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o retail rates and service in rural areas; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o certification of new transmission lines; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o extensions of service into new areas. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States' Louisiana electric and gas business and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana are subject to regulation by the LPSC as to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o utility service; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o rates and charges; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o certification of generating facilities; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o power or capacity purchase contracts; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o depreciation, accounting, and other matters. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana is also subject to the jurisdiction of the Council \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with respect to such matters within Algiers in Orleans Parish. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi is subject to regulation by the MPSC as to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql following: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o utility service; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o service areas; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o facilities; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o retail rates. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi is also subject to regulation by the APSC as to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the certificate of environmental compatibility and public need for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Independence Station, which is located in Arkansas. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans is subject to regulation by the Council as to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the following: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o utility service; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o rates and charges; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o standards of service; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o depreciation, accounting, and issuance and sale of certain \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql securities; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o other matters. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Franchises \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas holds exclusive franchises to provide electric \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql service in approximately 304 incorporated cities and towns in Arkansas. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql These franchises are unlimited in duration and continue unless the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql municipalities purchase the utility property. In Arkansas, franchises \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql are considered to be contracts and, therefore, are terminable upon breach \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the terms of the franchise. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States holds non-exclusive franchises, permits, or \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql certificates of convenience and necessity to provide electric and gas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql service in approximately 55 incorporated municipalities in Louisiana and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to provide electric service in approximately 63 incorporated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql municipalities in Texas. Entergy Gulf States typically is granted 50- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql year franchises in Texas and 60-year franchises in Louisiana. Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States' current electric franchises will expire during 2007 - 2036 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in Texas and during 2015 - 2046 in Louisiana. The natural gas franchise \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in the City of Baton Rouge will expire in 2015. In addition, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States holds a certificate of convenience and necessity from the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PUCT to provide electric service to areas within 21 counties in eastern \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Texas. Retail open access is scheduled to begin in Entergy Gulf States' \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Texas service territory on January 1, 2002. Refer to "MANAGEMENT'S \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FINANCIAL DISCUSSION AND ANALYSIS - SIGNIFICANT FACTORS AND KNOWN TRENDS" \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and Note 2 to the financial statements for discussions of the transition \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to competition in Texas. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana holds non-exclusive franchises to provide electric \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql service in approximately 116 incorporated Louisiana municipalities. Most \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of these franchises have 25-year terms, although six of these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql municipalities have granted 60-year franchises. Entergy Louisiana also \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql supplies electric service in approximately 353 unincorporated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql communities, all of which are located in Louisiana parishes in which it \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql holds non-exclusive franchises. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi has received from the MPSC certificates of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql public convenience and necessity to provide electric service to areas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql within 45 counties, including a number of municipalities, in western \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi. Under Mississippi statutory law, such certificates are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql exclusive. Entergy Mississippi may continue to serve in such \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql municipalities upon payment of a statutory franchise fee, regardless of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql whether an original municipal franchise is still in existence. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans provides electric and gas service in the City of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans pursuant to city ordinances (except for in Algiers, which is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql served by Entergy Louisiana). These ordinances contain a continuing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql option for the City of New Orleans to purchase Entergy New Orleans' \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql electric and gas utility properties. A resolution to study the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql advantages for ratepayers that might result from an acquisition of these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql properties has been filed in a committee of the Council. The committee \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql has deferred consideration of that resolution until May 2001. The full \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Council must approve the resolution to commence such a study before it \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql can become effective. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The business of System Energy is limited to wholesale power sales. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql It has no distribution franchises. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Environmental Regulation \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql General \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's facilities and operations are subject to regulation by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql various domestic and foreign governmental authorities having jurisdiction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql over air quality, water quality, control of toxic substances and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql hazardous and solid wastes, and other environmental matters. Management \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql believes that its affected subsidiaries are in substantial compliance \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with environmental regulations currently applicable to their facilities \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and operations. Because environmental regulations are subject to change, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql future compliance costs cannot be precisely estimated. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Clean Air Legislation \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The Clean Air Act Amendments of 1990 (the Act) established the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql following three programs that currently or in the future may affect \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's fossil-fueled generation: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an acid rain program for control of sulfur dioxide (SO2) and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql nitrogen oxides (NOx); \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an ozone nonattainment area program for control of NOx and volatile \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql organic compounds; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an operating permits program for administration and enforcement of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql these and other Act programs. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Under the current acid rain program, Entergy's subsidiaries will not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql require additional equipment to control SO2 or NOx. The Act provides SO2 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql allowances to most of the affected Entergy generating units for emissions \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql based upon past emission levels and operating characteristics. Each \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql allowance is an entitlement to emit one ton of SO2 per year. Under the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Act, utilities are or will be required to possess allowances for SO2 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql emissions from affected generating units. All Entergy fossil-fueled \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generating units are classified as "Phase II" units under the Act and are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql subject to SO2 allowance requirements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Additional controls were recently implemented at certain Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States generating units to achieve NOx reductions due to the ozone \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql non-attainment status of areas served in and around Beaumont and Houston, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Texas. Texas environmental authorities imposed NOx controls on power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql plants that had to be in place by November 1999. To date, the cost of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql additional control equipment necessary to maintain this compliance is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql immaterial. In December 1999 and August 2000, Texas authorities proposed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql future control strategies for public comment that would affect the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Beaumont and Houston areas, respectively. The Texas authorities \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql finalized regulations for the Beaumont area in April 2000. The analogous \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Houston area regulations were finalized in December 2000. The final \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql strategies adopted by the state of Texas will cause Entergy Gulf States \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to incur additional costs for NOx controls through 2007. Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States has conducted studies to estimate the costs that would be incurred \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql based on the proposed strategies. Pursuant to these studies, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States' preliminary estimate is that compliance costs through 2003 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in the Beaumont and Houston areas will be $37 million and $26 million \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql respectively, and that these expenditures will be sufficient for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql entire compliance period through 2007. Entergy commenced projects in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 to engineer, procure, and construct needed air pollution control \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql facilities. Cost estimates will be refined as engineering design \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql progresses based on the final adopted strategies approved by the EPA. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy believes the future control strategies in the ozone non- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql attainment regulations require emission limits that are more restrictive \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql than those discussed below related to utility restructuring in Texas. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql As part of legislation passed in Texas in June 1999 to restructure \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the electric power industry in the state, certain generating units of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States will be required to obtain operating permits and meet \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql new, lower emission limits for NOx. It is expected that Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States will incur costs through 2003 to meet these new standards. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Texas portion of these costs and the costs associated with ozone non- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql attainment regulations are expected to be recoverable as stranded costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of environmental cleanup. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Oil Pollution Prevention and Response \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The EPA has issued a proposed rule on oil pollution prevention and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql response. This rule could affect Entergy's operation of its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approximately 3,500 transmission and distribution electrical equipment \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql installations that are potentially subject to this proposed rule. If the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql proposed rule is issued in the form expected by the industry, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql will be substantially in compliance with the rule. However, there is a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql possibility that the rule could be issued in a form that would require \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy to develop site-specific oil spill prevention and control \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql countermeasure plans for the facilities subject to this rule. In \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql addition, secondary containment could be required around the equipment in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql these facilities. Entergy participates in industry groups involved with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the proposed rule and will be monitoring the development of the proposed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rule. It is expected that the final rule will be issued in the first \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql half of 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other Environmental Matters \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The Comprehensive Environmental Response, Compensation, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Liability Act of 1980, as amended (CERCLA), authorizes the EPA and, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql indirectly, the states, to mandate cleanup, or reimbursement of clean-up \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs, by owners or operators of sites from which hazardous substances \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql may be or have been released. Parties that generated or transported \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql hazardous substances to these sites are also deemed liable by CERCLA. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql CERCLA has been interpreted to impose joint and several liability on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql responsible parties. The domestic utility companies have sent waste \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql materials to various disposal sites over the years. In addition, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql environmental laws now regulate certain of the domestic utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies' operating procedures and maintenance practices, which \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql historically were not subject to regulation. Some of Entergy's disposal \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql sites have been the subject of governmental action under CERCLA, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql resulting in site clean-up activities. The domestic utility companies \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql have participated to various degrees in accordance with their respective \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql potential liabilities in such site cleanups and have developed experience \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with clean-up costs. The affected domestic utility companies have \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql established reserves for such environmental clean up and restoration \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql activities. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas entered into a Consent Administrative Order with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Arkansas Department of Environmental Quality (ADEQ) in which it \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql agreed to conduct initial stabilization associated with contamination at \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Utilities Services, Inc. Superfund site located near Rison, Arkansas. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql This site was never owned nor operated by any Entergy-affiliated company. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql This site was found to have soil contaminated by polychlorinated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql biphenyls (PCBs) and pentachlorophenol (a wood preservative). Containers \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and drums that contained PCBs and other hazardous substances were found \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql at the site. Entergy Arkansas worked with the ADEQ to identify and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql notify other PRPs with respect to this site. Approximately twenty PRPs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql have been identified to date. In December 1999, Entergy Arkansas, along \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with several other PRPs, met with ADEQ representatives to discuss the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cleanup of the site. The PRPs are being encouraged to undertake a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql voluntary cleanup and have begun discussions regarding the sharing of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs. Entergy Arkansas believes that its ultimate responsibility for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql this site will not materially exceed its existing cleanup provision of $5 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million. Entergy has sent a letter of intent to the ADEQ to participate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in the site characterization, and Entergy is waiting for a response from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the ADEQ. As of December 31, 2000, Entergy Arkansas had incurred \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approximately $400,000 of these costs. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Several class action and other suits have been filed in state and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql federal courts seeking relief from Entergy Gulf States and others for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql damages caused by the disposal of hazardous waste and for asbestos- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql related disease allegedly resulting from exposure on Entergy Gulf States' \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql premises (see "Other Regulation and Litigation" below). \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In August 1999, Entergy Gulf States received notice from the Texas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Natural Resource Conservation Commission (TNRCC) that it is considered to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql be a PRP for the Spector Salvage Yard in Orange, Texas. The Spector \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Salvage site operated from approximately 1944 until 1971. In addition to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql general salvage, the facility functioned as a repository for military \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql surplus equipment and supplies purchased from military, industrial, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql chemical facilities. Soil samples from the site indicate the presence of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql heavy metals and various organics, including PCBs. The TNRCC requested \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of all PRPs a submission of a good faith offer to fully fund or conduct a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql remedial investigation. Entergy Gulf States believes that there is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql insufficient basis for including the company as a PRP. If additional \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql evidence that the company is a PRP were discovered, Entergy Gulf States \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql would re-evaluate its position. Based on the size of the site, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States expects that its future expenditures for investigation and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql clean-up should not exceed $250,000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States is currently involved in a remedial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql investigation of the Lake Charles Service Center site, located in Lake \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Charles, Louisiana. A manufactured gas plant (MGP) is believed to have \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operated at this site from approximately 1916 to 1931. Coal tar, a by- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql product of the distillation process employed at MGPs, was apparently \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql routed to a portion of the property for disposal. The same area has also \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql been used as a landfill. In 1999, Entergy Gulf States signed a second \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Administrative Consent Order with the EPA to perform removal action at \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the site. Entergy Gulf States believes that its ultimate responsibility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for this site will not materially exceed its existing clean-up provision \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of $16.8 million. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States is currently involved in the second phase of an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql investigation of contamination of an MGP site, known as the Old Jennings \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Ice Plant, located in Jennings, Louisiana. The MGP is believed to have \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operated from approximately 1909 to 1926. The site is currently used for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql an electrical substation and storage of transmission and distribution \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql equipment. In July 1996, a petroleum-like substance was discovered on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the surface soil, and notification was made to the LDEQ. The LDEQ was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql aware of this site based upon a survey performed by an environmental \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql consultant for the EPA. Entergy Gulf States obtained the services of an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql environmental consultant to collect core samples and to perform a search \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of historical records to determine what activities occurred at Jennings. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Results of the core sampling, which found limited amounts of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contamination on-site, were submitted to the LDEQ. A plan to determine a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cost-effective remediation strategy will be developed and submitted to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the LDEQ for review in 2001. Entergy does not expect that its ultimate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial responsibility with respect to this site will be material. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amount of its existing provision for cleanup is $250,000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1994, Entergy Gulf States performed a site assessment in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql conjunction with a construction project at the Louisiana Station \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Generating Plant (Louisiana Station). In 1995, a further assessment \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql confirmed subsurface soil and groundwater impact to three areas on the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql plant site. After further evaluation, a notification was made to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LDEQ. Remediation of Louisiana Station is expected to continue through \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2001. The remediation cost incurred through December 31, 2000 for this \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql site was $6.2 million. Future costs are not expected to exceed the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql existing provision of $1.3 million. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans is planning a new substation on a parcel of land \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql located adjacent to an existing substation, which is in close proximity \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to the former Market Street power plant. During pre-construction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql activities in January 2000, significant levels of lead were discovered in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the soil at this site. Entergy New Orleans notified the LDEQ of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contamination. The contamination at this site was addressed using the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LDEQ Risk/Evaluation Corrective Action Plan. The work has been completed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and the final closure report is scheduled to be submitted in the first \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql quarter of 2001. The cost of this remediation was approximately $1 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana and Entergy New Orleans \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The Southern Transformer shop located in New Orleans has served both \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana and Entergy New Orleans. This transformer shop is now \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql being closed and an environmental assessment is being performed to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql determine what remediation may be necessary. Based on preliminary \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql findings, Entergy Louisiana has reserved $150,000 for this project. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql From 1992 to 1994, Entergy Louisiana performed a site assessment and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql remedial activities at a retired power plant known as the Thibodaux \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql municipal site, previously owned and operated by a Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql municipality. Entergy Louisiana purchased the power plant at this site \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql as part of the acquisition of municipal electric systems. The site \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql assessment indicated some subsurface contamination from fuel oil. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Remediation of the Thibodaux site is expected to continue through 2001. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The cost incurred through December 31, 2000 for the Thibodaux site was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approximately $580,000. Future costs are not expected to exceed the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql existing provision of $240,000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql During 1993, the LDEQ issued new rules for solid waste regulation, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql including regulation of wastewater impoundments. Entergy Louisiana and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans have determined that certain of their power plant \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql wastewater impoundments were affected by these regulations and chose to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql upgrade or close them. Completion of this work is pending LDEQ approval. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LDEQ has issued notices of deficiencies for certain of these sites. As a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql result, a remaining recorded liability in the amount of $5.8 million for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana and $0.5 million for Entergy New Orleans existed at \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, 2000 for wastewater upgrades and closures. Management of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana and Entergy New Orleans believes these reserves are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adequate based on current estimates. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other Regulation and Litigation \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation and Entergy Gulf States Merger \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Several parties, including Entergy Services, appealed FERC's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approval of the merger between Entergy Corporation and Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States to the D.C. Circuit. Entergy Services sought review of FERC's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deletion of a 40% cap on the amount of fuel savings Entergy Gulf States \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql may be required to transfer to other domestic utility companies under a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql tracking mechanism designed to protect the other companies from certain \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql unexpected increases in fuel costs. The other parties sought to overturn \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FERC's decisions on various grounds, including issues as to whether FERC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql appropriately conditioned the merger to protect various interested \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql parties from alleged harm and FERC's reliance on Entergy's transmission \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql tariff to mitigate any potential anti-competitive impacts of the merger. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management cannot predict the timing or outcome of this proceeding. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Employment Litigation (Entergy Corporation, Entergy Arkansas, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States, Entergy Louisiana, Entergy Mississippi, and Entergy New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation and the domestic utility companies are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql defendants in numerous lawsuits that have been filed by former employees \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql alleging that they were wrongfully terminated and/or discriminated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql against on the basis of age, race, and/or sex. Entergy Corporation and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the domestic utility companies are vigorously defending these suits and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deny any liability to the plaintiffs. However, no assurance can be given \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql as to the outcome of these cases, and at this time management cannot \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql estimate the total amount of damages sought. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Asbestos and Hazardous Waste Suits (Entergy Gulf States) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Plaintiffs have filed numerous lawsuits in state and federal courts \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in Texas and Louisiana seeking relief from Entergy Gulf States as well as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql numerous other defendants for damages caused to the plaintiffs or others \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by the alleged exposure to hazardous waste and asbestos on the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql defendants' premises. The plaintiffs in some suits are also suing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States and all other defendants on a conspiracy claim. It \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql will not be known until discovery is complete how many of the plaintiffs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in any of the foregoing cases actually worked on Entergy Gulf States' \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql premises, nor can management, at this time, estimate the total amount of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql damages sought. Entergy Gulf States believes that the ultimate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql resolution of these matters will not be material, in the aggregate, to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql its financial position or results of operations. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Ratepayer Lawsuits (Entergy Corporation, Entergy Gulf States, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana, and Entergy New Orleans) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana Fuel Clause Lawsuit \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In May 1998, a group of ratepayers filed a complaint against Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Corporation, Entergy Power, and Entergy Louisiana in state court in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans Parish purportedly on behalf of all Entergy Louisiana ratepayers. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The plaintiffs seek treble damages for alleged injuries arising from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql alleged violations by the defendants of Louisiana's antitrust laws in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql connection with the costs included in fuel filings with the LPSC and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql passed through to ratepayers. Among other things, the plaintiffs allege \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that Entergy Louisiana improperly introduced certain costs into the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql calculation of the fuel charges, including high-cost electricity \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql imprudently purchased from its affiliates and high-cost gas imprudently \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchased from independent third party suppliers. In addition, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql plaintiffs seek to recover interest and attorneys' fees. Plaintiffs also \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql requested that the LPSC initiate a review of Entergy Louisiana's monthly \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel adjustment charge filings and force restitution to ratepayers of all \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs that the plaintiffs allege were improperly included in those fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adjustment filings. A few parties have intervened in the LPSC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql proceeding. In direct testimony, plaintiffs purport to quantify many of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql their claims for the period 1989 through 1998 in an amount totaling \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $544 million, plus interest. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana has reached an agreement in principle with the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LPSC staff for the settlement of the matter before the LPSC and has \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql executed a definitive agreement with the plaintiffs for the settlement of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the matter before the LPSC and the state court. The LPSC approved the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql settlement agreement following a fairness hearing before an ALJ in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql November 2000. Plaintiffs have sought class certification and approval \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the settlement by the state court, and a hearing on those issues is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql scheduled for April 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Under the terms of the settlement agreement, Entergy Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql agrees to refund to customers approximately $72 million to resolve all \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql claims arising out of or relating to Entergy Louisiana's fuel adjustment \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql clause filings from January 1, 1975 through December 31, 1999, except \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with respect to purchased power and associated costs included in the fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adjustment clause filings for the period May 1 through September 30, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999. Entergy Louisiana previously provided reserves for the refund. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Under the terms of the settlement, Entergy Louisiana also consents to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql future fuel cost recovery under a long-term gas contract based on a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql formula that would likely result in an under-recovery of actual costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql under that contract for the remainder of its term, which runs through \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2013. The future under-recovery cannot be precisely estimated at this \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql time because it will depend upon factors that are not certain, such as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the price of gas and the amount of gas purchased under the long-term \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contract. In recent years, Entergy Louisiana has made purchases under \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that contract totaling from $91 million to $121 million annually. Had \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the proposed settlement terms been applicable to such purchases, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql under-recoveries would have ranged from $4 million to $9 million per \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql year. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Vidalia Project Sub-Docket \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Two of the intervenors in the proceeding discussed above, Marathon \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Oil Company and Louisiana Energy Users Group, requested that the LPSC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql review the prudence of a contract entered into by Entergy Louisiana to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchase energy generated by a hydroelectric facility known as the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Vidalia project through the year 2031. Note 9 to the financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements contains further discussions of the obligations related to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Vidalia project. By orders entered by the LPSC in 1985 and 1990, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LPSC approved Entergy Louisiana's entry into the Vidalia contract and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana's right to recover, through the fuel adjustment clause, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the costs of power purchased thereunder. Additionally, the wholesale \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql electric rates under the Vidalia power purchase contract were filed at \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FERC. In December 1999, the LPSC instituted a review of the following \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql issues relating to the Vidalia project: (i) the LPSC's jurisdiction over \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Vidalia project; (ii) Entergy Louisiana's management of the Vidalia \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contract, including opportunities to restructure or otherwise reform the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contract; (iii) the appropriateness of Entergy Louisiana's recovery of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 100% of the Vidalia contract costs from ratepayers; (iv) the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql appropriateness of the fuel adjustment clause as the method for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovering all or part of the Vidalia contract costs; (v) the appropriate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulatory treatment of the Vidalia contract in the event the LPSC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approves implementation of retail competition; and (vi) Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana's communication of pertinent information to the LPSC regarding \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Vidalia project and contract. Based on its review, the LPSC will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql determine whether it should disallow any of the costs of the Vidalia \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql project included in the fuel adjustment clause. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In March 2000, Entergy Louisiana filed testimony in this sub-docket \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql asserting that the prudence of the Vidalia contract already has been \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approved by final orders of the LPSC and that recovery of all amounts \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql paid by Entergy Louisiana related to the Vidalia project pursuant to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FERC-filed rate is appropriate. Direct testimony was filed by intervenor \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Marathon Oil Company in May 2000 and by the LPSC staff and intervenor \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana Energy Users Group in July 2000. In its testimony the LPSC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql staff alleges that Entergy Louisiana was imprudent for not declaring to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the LPSC that the Vidalia project had become uneconomic and not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql threatening to block the Vidalia project's owners' July 30, 1990 request \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that the LPSC clarify the LPSC's 1985 order (approving the Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana/Vidalia project power purchase agreement), unless the Vidalia \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql project's owners' shared with Entergy Louisiana's ratepayers some portion \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of what the LPSC staff quantifies as approximately $90 million of tax \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql consequences available to the project. The LPSC staff's testimony does \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql not quantify how much of the potential tax savings Entergy Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql should have demanded in exchange for not attempting to block the Vidalia \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql project's owners' request for clarification; however, that testimony does \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql suggest various alternatives by which some portion of the $90 million, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql perhaps $45 million plus interest since 1990, could be returned to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ratepayers. The direct testimony of the intervenor Louisiana Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Users Group alleges that Entergy Louisiana was imprudent for not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql attempting to block the Vidalia project's owners' July 30, 1990 request \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that the LPSC clarify the LPSC's 1985 order approving the Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana/Vidalia project power purchase agreement; however, that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql intervenor does not quantify the amount of damage alleged to have been \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql caused by this alleged imprudence. The direct testimony of the intervenor \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Marathon Oil Company alleges with respect to Entergy Louisiana that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql imprudent Vidalia project costs should be disallowed and that Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana's customers should not be charged 100% of the Vidalia costs. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql It is anticipated that hearings in this sub-docket concerning the Vidalia \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contract will begin in April 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans Fuel Clause Lawsuit \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In April 1999, a group of ratepayers filed a complaint against \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans, Entergy Corporation, Entergy Services, and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Power in state court in Orleans Parish purportedly on behalf of all \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans ratepayers. The plaintiffs seek treble damages for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql alleged injuries arising from the defendants' alleged violations of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana's antitrust laws in connection with certain costs passed on to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ratepayers in Entergy New Orleans' fuel adjustment filings with the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Council. In particular, plaintiffs allege that Entergy New Orleans \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql improperly included certain costs in the calculation of fuel charges and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that Entergy New Orleans imprudently purchased high-cost fuel from other \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy affiliates. Plaintiffs allege that Entergy New Orleans and the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql other defendant Entergy companies conspired to make these purchases to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the detriment of Entergy New Orleans' ratepayers and to the benefit of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's shareholders, in violation of Louisiana's antitrust laws. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Plaintiffs also seek to recover interest and attorney's fees. Exceptions \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to the plaintiffs' allegations were filed by Entergy, asserting, among \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql other things, that jurisdiction over these issues rests with the Council \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and FERC. If necessary, at the appropriate time, Entergy will also raise \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql its defenses to the antitrust claims. At present, the suit in state \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql court is stayed by stipulation of the parties. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Plaintiffs also filed this complaint with the Council in order to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql initiate a review by the Council of the plantiffs' allegations and to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql force restitution to ratepayers of all costs they allege were improperly \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and imprudently included in the fuel adjustment filings. Discovery has \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql begun in the proceedings before the Council. In April 2000, testimony \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql was filed on behalf of the plaintiffs in this proceeding. The testimony \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql asserts, among other things, that Entergy New Orleans and other \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql defendants have engaged in fuel procurement and power purchasing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql practices that could have resulted in New Orleans customers being \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql overcharged by more than $59 million over a period of years. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql testimony also challenges the implementation of the recovery methodology. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql However, it is not clear precisely what periods and damages are being \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql alleged. Entergy intends to defend this matter vigorously, both in court \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and before the Council. The ultimate outcome of the lawsuit and the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Council proceeding cannot be predicted at this time. Hearings are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expected to begin in October 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans Rate of Return Lawsuit \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In April 1998, a group of residential and business ratepayers filed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql a complaint against Entergy New Orleans in state court in Orleans Parish \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purportedly on behalf of all ratepayers in New Orleans. The plaintiffs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql allege that Entergy New Orleans overcharged ratepayers by at least $300 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million since 1975 in violation of limits on Entergy New Orleans' rate of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql return that the plaintiffs allege were established by ordinances passed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by the Council in 1922. The plaintiffs seek, among other things, (i) a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql declaratory judgment that such franchise ordinances have been violated; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and (ii) a remand to the Council for the establishment of the amount of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql overcharges plus interest. Entergy New Orleans believes the lawsuit is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql without merit. Entergy New Orleans has charged only those rates \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql authorized by the Council in accordance with applicable law. In May \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, a court of appeal granted Entergy New Orleans' exception to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql jurisdiction in the case and dismissed the proceeding. The Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Supreme Court denied the plaintiff's request for a writ of certiorari. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The plaintiffs then commenced a similar proceeding before the Council. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management cannot predict the outcome of the proceeding before the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Council. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana Formula Ratemaking Plan Lawsuit \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In May 1998, a group of ratepayers filed a complaint against Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana in state court in East Baton Rouge Parish purportedly on behalf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of all Entergy Louisiana ratepayers. The plaintiffs allege that the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql formula ratemaking plan authorized by the LPSC has allowed Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana to earn amounts in excess of a fair return. The plaintiffs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql seek, among other things, (i) a declaratory judgment that the formula \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ratemaking plan is an improper ratemaking practice; and (ii) a refund of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the amounts allegedly charged in excess of proper ratemaking practices. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana believes the lawsuit is without merit and is vigorously \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql defending itself. At this time, management cannot determine the amount \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of damages being sought. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql July 1999 Power Outages Lawsuit \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In February 2000, a lawsuit was commenced in state court in Orleans \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Parish, Louisiana, against Entergy, Entergy Gulf States, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana, and Entergy New Orleans relating to power outages that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql occurred in July 1999. The plaintiff, who purports to represent a class \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of similarly situated persons, claims unspecified damages as a result of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql these outages, which the plaintiff claims were the result of negligence \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql on the part of the Entergy defendants. Plaintiffs have instituted a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql similar proceeding before the LPSC. The defendants will vigorously \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contest the plaintiff's allegations, which they believe do not support \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql any liability to the plaintiff for damages. At this time, management \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cannot determine the amount of damages being sought. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Franchise Fee Litigation (Entergy Corporation and Entergy Gulf States) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In September 1998, the City of Nederland filed a petition against \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States and Entergy Services in state court in Jefferson \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql County, Texas, purportedly on behalf of all Texas municipalities that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql have ordinances or agreements with Entergy Gulf States. The lawsuit \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql alleges that Entergy Gulf States has been underpaying its franchise fees \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to failure to properly calculate its gross receipts. The plaintiff \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql seeks a judgment for the allegedly underpaid fees and punitive damages. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States believes the lawsuit is without merit and is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql vigorously defending itself. The trial in this matter is scheduled to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql begin in December 2001. At this time, management cannot determine the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amount of damages being sought. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fiber Optic Cable Litigation (Entergy Corporation, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In May 1998, a group of property owners filed a petition against \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation, Entergy Gulf States, Entergy Services, and ETHC in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql state court in Jefferson County, Texas purportedly on behalf of all \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql property owners throughout the Entergy service area who have conveyed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql easements to the defendants. The lawsuit alleged that Entergy installed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fiber optic cable across their property without obtaining appropriate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql easements. The plaintiffs sought actual damages for the use of the land \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and a share of the profits made through use of the fiber optic cables \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and punitive damages. The state court petition was dismissed, and the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql plaintiffs have commenced an identical lawsuit in the United States \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql District Court in Beaumont, Texas. Entergy is vigorously defending \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql itself in the lawsuit and believes that any damages suffered by the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql plaintiff landowners are negligible and that there is no basis for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql claim seeking a share of profits. Recently both sides have filed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql motions for summary judgment. At this time, management cannot determine \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the amount of damages being sought. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Franchise Service Area Litigation (Entergy Gulf States) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In early 1998, Beaumont Power and Light Company (BP&L) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql unsuccessfully sought a franchise to provide electric service in the City \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Beaumont, Texas, where Entergy Gulf States already holds a franchise. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In November 1998, BP&L filed a request before the PUCT to obtain a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql certificate of convenience and necessity (CCN) for those portions of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Jefferson County outside the boundaries of any municipality for which \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States provides retail electric service. BP&L's application \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contemplates using Entergy Gulf States' facilities in their provision of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql service. In Texas, utilities are required to obtain a CCN prior to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql providing retail electric service. Jefferson County is currently singly \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql certificated to Entergy Gulf States. If BP&L's application is granted, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql BP&L would be able to provide retail service to Entergy Gulf States' \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql customers in the area for which the certificate would apply. BP&L has \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amended its application to add a request for a CCN to provide retail \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql electric service within the City of Beaumont. The amended application \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql acknowledges that the Texas electric utility restructuring law requires \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql BP&L to use its own facilities to connect to its customers if it is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql granted a CCN. In April 2000, the ALJ recommended denial of BP&L's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql application. In May 2000, the PUCT voted to remand the proceeding back \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to the ALJ to allow BP&L to provide further evidence. A pre-hearing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql conference has been scheduled for May 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Hindusthan Development Corporation, Ltd. (Entergy Corporation) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In January 1999, Hindusthan Development Corporation (HDC) commenced \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql an arbitration proceeding in India against Entergy Power Asia Ltd. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (EPAL), an indirect, wholly-owned subsidiary of Entergy Corporation. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql arbitration is progressing under rules that have been adopted in both \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql India and the United States. HDC alleges that EPAL did not fulfill its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql obligations under a Joint Development Agreement (JDA) to develop a 350 MW \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cogeneration plant to be built in Bina, India. HDC also alleges that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql EPAL wrongfully withdrew as lead developer. Entergy's management \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql believes that HDC's allegations are without merit, and that each party to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the JDA had an absolute right of withdrawal. HDC is seeking unspecified \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql damages of $1.1 billion. EPAL is vigorously defending itself in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql arbitration proceeding. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Ice Storm Litigation (Entergy Corporation and Entergy Gulf States) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In January 1997, a group of Entergy Gulf States customers in Texas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql filed a lawsuit against Entergy Corporation, Entergy Gulf States, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql other Entergy subsidiaries in state court in Jefferson County, Texas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purportedly on behalf of all Entergy Gulf States customers in Texas who \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql sustained outages in a January 1997 ice storm. The lawsuit alleges that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy failed to properly maintain its electrical distribution system \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and respond to the ice storm. The district court certified the class in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql April 1999. In March 2000, an appellate court affirmed the district \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql court's decision to certify the class. In response to Entergy's motion \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for rehearing, the appellate court reversed the district court, denied \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql class certification, and remanded the case to the district court for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql proceedings consistent with its ruling. This ruling reduces Entergy's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql exposure in the lawsuit to an immaterial level. Entergy believes that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the lawsuit is without merit, and will vigorously defend itself against \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the individual named plaintiffs. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Litigation Environment (Entergy Corporation, Entergy Arkansas, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and System Energy) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The four states in which the domestic utility companies operate, in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql particular Louisiana, Mississippi, and Texas, have proven to be unusually \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql litigious environments. Judges and juries in Louisiana, Mississippi, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Texas have demonstrated a willingness to grant large verdicts, including \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql punitive damages, to plaintiffs in personal injury, property damage, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql business tort cases. Entergy uses legal and appropriate means to contest \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql litigation threatened or filed against it, but the litigation environment \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in these states poses a significant business risk. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql EARNINGS RATIOS OF DOMESTIC UTILITY COMPANIES AND SYSTEM ENERGY \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The domestic utility companies' and System Energy's ratios of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql earnings to fixed charges and ratios of earnings to combined fixed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql charges and preferred dividends pursuant to Item 503 of SEC Regulation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql S-K are as follows: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Ratios of Earnings to Fixed Charges \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 1997 1996 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas 3.01 2.08 2.63 2.54 2.93 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States 2.60 2.18 1.40 1.42 1.47 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana 3.33 3.48 3.18 2.74 3.16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi 2.33 2.44 3.12 2.98 3.40 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans 2.66 3.00 2.65 2.70 3.51 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy 2.41 1.90 2.52 2.31 2.21 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Ratios of Earnings to Combined Fixed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Charges and Preferred Dividends \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 1997 1996 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas 2.70 1.80 2.28 2.24 2.44 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States(a) 2.39 1.86 1.20 1.23 1.19 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana 2.93 3.09 2.75 2.36 2.64 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi 2.09 2.18 2.80 2.69 2.95 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans 2.43 2.74 2.41 2.44 3.22 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a) "Preferred Dividends" in the case of Entergy Gulf States also \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql include dividends on preference stock. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql BUSINESS SEGMENTS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's business segments are discussed in Note 14 to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql As of December 31, 2000, Entergy New Orleans operating revenues and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql customer data were as follows: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Electric Operating Natural Gas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Revenue Revenue \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Residential 41% 52% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Commercial 37% 22% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Industrial 6% 10% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Governmental/Municipal 16% 16% \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Number of Customers 190,000 150,000 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the year ended December 31, 2000, 98% of Entergy Gulf States' \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operating revenue was derived from the electric utility business and 2% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql from the natural gas business. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Financial Information Relating to Products and Services \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Financial information relating to Entergy New Orleans' and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States' products and services is presented in their respective \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PROPERTY \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Generating Stations \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Domestic Utility Companies and System Energy \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The total capability of the generating stations owned and leased by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the domestic utility companies and System Energy as of December 31, 2000, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by company and by fuel type, is indicated below: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Owned and Leased Capability MW(1) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Turbine \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Internal \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Company Total Fossil Nuclear Combustion Hydro \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas 4,576 2,758 1,714 34 70 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States 6,625 5,685 940 - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana 5,365 4,260 1,093 12 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi 2,926 2,919 - 7 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans 978 967 - 11 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy 1,110 - 1,110 - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------ ------ ----- -- -- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total 21,580 16,589 4,857 64 70 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ====== ====== ===== == == \par\pard\plain\fs16\par\pard\plain\cf1\f50\fs16\ql (1) "Owned and Leased Capability" is the dependable load carrying \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql capability as demonstrated under actual operating conditions based \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql on the primary fuel (assuming no curtailments) that each station was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql designed to utilize. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's domestic utility business is subject to seasonal \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fluctuations, with the peak period occurring in the summer months. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 peak demand of 22,052 MW occurred on August 30, 2000, which was an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql all-time high for the Entergy system. Entergy's load and capacity \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql projections are reviewed periodically to assess the need and timing for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql additional generating capacity and interconnections in light of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql availability of power, the location of new loads, and maximum economy to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy. Domestically, based on load and capability projections and bulk \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power availability, Entergy's domestic utility companies expect to meet \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the need for new generation resources by means other than construction of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql new base load generating capacity. Entergy's domestic utility companies \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expect to meet future capacity needs by, among other things, purchasing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in the wholesale power market, including plans to contract for up to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 3,000 MW of purchased power to meet the expected needs of the domestic \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility companies in the summer of 2001. Entergy also reactivated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql several units in 1999 and 2000 that were in extended reserve shutdown to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql assist in serving customers during periods of peak demand. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Under the terms of the System Agreement, generating capacity and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql other power resources are shared among the domestic utility companies. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The System Agreement provides, among other things, that parties having \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generating reserves greater than their load requirements (long companies) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql shall receive payments from those parties having deficiencies in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generating reserves (short companies). Such payments are at amounts \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql sufficient to cover certain of the long companies' costs, including \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operating expenses, fixed charges on debt, dividend requirements on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql preferred and preference stock, and a fair rate of return on common \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql equity investment. Under the System Agreement, these charges are based \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql on costs associated with the long companies' steam electric generating \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql units fueled by oil or gas. In addition, for all energy exchanged among \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the domestic utility companies under the System Agreement, the short \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies are required to pay the cost of fuel consumed in generating \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql such energy plus a charge to cover other associated costs. FERC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql proceedings relating to proposed amendments to the System Agreement are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql discussed more thoroughly in "RATE MATTERS AND REGULATION - Rate Matters \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql - Wholesale Rate Matters - System Agreement," above. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Global Power Development Business \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Power owns 665 MW of fossil-fueled capacity at the Ritchie 2 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and Independence plants. In addition, Entergy's global power development \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql business has completed construction of two combined cycle gas turbine \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql merchant power plants in the UK. Saltend, a 1,200 MW plant located in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql northeast England, provides up to 120 tons/hr of steam and 100 MW of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power to BP Chemical's nearby complex with the remaining electricity sold \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql into the UK national power pool. Commercial operation commenced in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql November 2000. The second plant, an 800 MW facility known as Damhead \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Creek, is located in southeast England. Commercial operation commenced \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's global power development business has begun construction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the Warren Power Project, a 300 MW combined-cycle gas turbine merchant \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power plant in Vicksburg, Mississippi. The construction costs are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expected to be approximately $150 million. Management expects that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commercial operation of the plant will begin in the summer of 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Domestic Non-Utility Nuclear Business \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In November 2000, Entergy's domestic non-utility nuclear business \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchased NYPA's 825 MW James A. FitzPatrick nuclear power plant located \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql near Oswego, New York and NYPA's 980 MW Indian Point 3 nuclear power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql plant located in Westchester County, New York. Entergy's domestic non- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility nuclear business also owns the 670 MW Pilgrim Nuclear Station in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Plymouth, Massachusetts. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interconnections \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The electric generating facilities of Entergy's domestic utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies consist principally of steam-electric production facilities. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql These generating units are interconnected by a transmission system \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operating at various voltages up to 500 KV. With the exception of a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql small portion of Entergy Mississippi's capacity, operating facilities or \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql interests therein generally are owned or leased by the domestic utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql company serving the area in which the generating facilities are located. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql All of these generating facilities are centrally dispatched and operated. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's domestic utility companies are interconnected with many \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql neighboring utilities. In addition, the domestic utility companies are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql members of the Southeastern Electric Reliability Council (SERC). The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql primary purpose of SERC is to ensure the reliability and adequacy of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql electric bulk power supply in the southeast region of the United States. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SERC is a member of the North American Electric Reliability Council. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The electric generating facilities of Entergy's domestic non-utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql nuclear business consist of the Pilgrim nuclear production facility, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql James A. FitzPatrick nuclear production facility, and the Indian Point 3 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql nuclear production facility. The Pilgrim nuclear production facility has \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql firm total output power purchase agreements with Boston Edison and other \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utilities that expire at the end of 2004. The James A. FitzPatrick \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql nuclear production facility has two long-term power purchase agreements \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with NYPA, one expiring at the end of 2003 and the other expiring at the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql end of 2004. The Indian Point 3 nuclear production facility has a long- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql term power purchase agreement with NYPA that expires at the end of 2004. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The Pilgrim plant is dispatched as a part of the New England Power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Pool (NEPOOL). The primary purpose of NEPOOL is to direct the operations \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the major generation and transmission facilities in the New England \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql region. The James A. FitzPatrick and Indian Point 3 plants are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql dispatched by the New York Independent System Operator (NYISO). The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql primary purpose of NYISO is to direct the operations of the major \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generation and transmission facilities in New York State. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gas Property \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql As of December 31, 2000, Entergy New Orleans distributed and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transported natural gas for distribution solely within the limits of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql City of New Orleans through a total of 1,459 miles of gas distribution \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql mains and 41 miles of gas transmission pipelines. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql As of December 31, 2000, the gas properties of Entergy Gulf States, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql which are located in and around Baton Rouge, Louisiana, were not material \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to Entergy Gulf States' financial position. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Titles \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The generating stations and major transmission substations of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's public utility companies are generally located on properties \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql owned in fee simple. The greater portion of the transmission and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql distribution lines of the domestic utility companies have been \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql constructed on property of private owners pursuant to easements or on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql public highways and streets pursuant to appropriate franchises. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rights of each company in the property on which its utility facilities \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql are located are considered by such company to be adequate for use in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql conduct of its business. Minor defects and irregularities customarily \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql found in properties of like size and character may exist, but such \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql defects and irregularities do not, in the opinion of management, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql materially impair the use of the properties affected thereby. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility companies generally have the right of eminent domain, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql whereby they may, if necessary, perfect or secure titles to, or easements \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql or servitudes on, privately held lands used in or reasonably necessary \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for their utility operations. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Substantially all of the physical properties and assets owned by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, and System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Energy are subject to the liens of mortgages securing the first mortgage \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql bonds of such company. The Lewis Creek generating station is owned by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql GSG&T, Inc., a subsidiary of Entergy Gulf States, and is not subject to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the lien of the Entergy Gulf States mortgage securing the first mortgage \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql bonds of Entergy Gulf States, but is leased to and operated by Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States. All of the debt outstanding under the original first \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql mortgages of Entergy Mississippi and Entergy New Orleans has been retired \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and the original first mortgages were cancelled in 1999 and 1997, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql respectively. As a result, the general and refunding mortgages of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi and Entergy New Orleans now each constitute a first \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql mortgage lien on substantially all of the respective physical properties \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and assets of these two companies. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FUEL SUPPLY \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The sources of generation and average fuel cost per KWH for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility companies and System Energy for the years 1998-2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql were: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Natural Gas Fuel Oil Nuclear Fuel Coal \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql % Cents % Cents % Cents % Cents \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Per of Per of Per of Per \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Year Gen KWH Gen KWH Gen KWH Gen KWH \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 42 4.90 4 3.90 39 .56 15 1.51 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999 45 2.75 4 2.06 35 .54 16 1.59 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1998 40 2.50 6 2.37 40 .53 14 1.67 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Actual 2000 and projected 2001 sources of generation for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility companies and System Energy are: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Natural Gas Fuel Oil Nuclear Coal \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 2001 2000 2001 2000 2001 2000 2001 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas (a) 11% 5% - - 53% 43% 35% 51% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States 61% 62% - - 24% 21% 15% 17% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana 56% 55% 2% - 42% 45% - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi 42% 57% 31% 14% - - 27% 28% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans 94% 96% 6% 4% - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy - - - - 100%(b) 100%(b) - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total (a) 42% 37% 4% 1% 39% 37% 15% 24% \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a) Hydroelectric power provided an immaterial amount of generation at \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas in 2000 and is expected to provide an immaterial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amount of generation in 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (b) In addition to the nuclear capacity given above for the following \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies, the Unit Power Sales Agreement allocates capacity and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql energy from System Energy's interest in Grand Gulf 1 as follows: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas - 36%; Entergy Louisiana - 14%; Entergy Mississippi \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql - 33%; and Entergy New Orleans - 17%. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Natural Gas \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The domestic utility companies have long-term firm and short-term \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql interruptible gas contracts. Long-term firm contracts comprise less than \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 26% of the domestic utility companies' total requirements but can be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql called upon, if necessary, to satisfy a significant percentage of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility companies' needs. Short-term contracts and spot-market \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchases satisfy additional gas requirements. Entergy Gulf States has a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transportation service agreement with a gas supplier that provides \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql flexible natural gas service to certain generating stations by using such \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql supplier's pipeline and gas storage facility. Entergy's global power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql development business has entered into 15-year gas supply contracts at the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql project level to supply up to 100% of the gas requirements for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Saltend and Damhead Creek power plants located in the UK. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Many factors, including wellhead deliverability, storage and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql pipeline capacity, and demand requirements of end users, influence the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql availability and price of natural gas supplies for power plants. Demand \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql is tied to weather conditions as well as to the prices of other energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql sources. Increased demand combined with decreased supply of natural gas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql caused a significant increase in the price of natural gas throughout \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000. Entergy's supplies of natural gas are expected to be adequate in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2001. However, pursuant to federal and state regulations, gas supplies \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to power plants may be interrupted during periods of shortage. To the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql extent natural gas supplies are disrupted or natural gas prices \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql significantly increase, the domestic utility companies will use alternate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuels, such as oil, or rely to a larger extent on coal and nuclear \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generation. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Coal \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas has long-term contracts for low-sulfur Wyoming coal \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for White Bluff and Independence. These contracts, which expire in 2002 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and 2011, respectively, provide for approximately 85% of Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas' expected annual coal requirements. Additional requirements are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql satisfied by spot market purchases. Entergy Gulf States has a contract \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for the supply of low-sulfur Wyoming coal for Nelson Unit 6, which should \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql be sufficient to satisfy its fuel requirements for that unit through 2010 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql if all price re-openers are accepted. If both parties cannot agree upon \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql a price, then the contract terminates. Effective April 1, 2000, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana Generating LLC assumed Cajun's ownership interest in the Big \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cajun 2 generating facilities and operates the plant. The management of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana Generating LLC has advised Entergy Gulf States that it has \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql executed coal supply and transportation contracts that should provide an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adequate supply of coal for the operation of Big Cajun 2, Unit 3 for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql foreseeable future. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas has a long-term railroad transportation contract \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for the delivery of coal to both White Bluff and Independence. This \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contract will expire in the year 2011. Entergy Arkansas has settled its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql lawsuit against the railroad that claimed breach of contract by the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql railroad and requested termination of the contract. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States has transportation requirements contracts with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql railroads to deliver coal to Nelson Unit 6 through December 31, 2004. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Each of the two contracts governs the movement of approximately one-half \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the plant's requirements and the base contract provides flexibility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for shipping up to all of the plant's requirements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nuclear Fuel \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The nuclear fuel cycle involves the following: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o mining and milling of uranium ore to produce a concentrate; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o conversion of the concentrate to uranium hexafluoride gas; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o enrichment of the hexafluoride gas; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o fabrication of nuclear fuel assemblies for use in fueling nuclear \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reactors; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o disposal of spent fuel. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Fuels is responsible for contracts to acquire nuclear \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql material to be used in fueling Entergy Arkansas', Entergy Louisiana's, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and System Energy's nuclear units. System Fuels also maintains \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql inventories of such materials during the various stages of processing. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Each of these companies purchases enriched uranium hexafluoride from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Fuels, but contracts separately for the fabrication of its own \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql nuclear fuel. The requirements for River Bend are pursuant to contracts \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql made by Entergy Gulf States. The requirements for Pilgrim, FitzPatrick, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and Indian Point 3 are pursuant to contracts made by Entergy's domestic \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql non-utility nuclear business. Entergy Nuclear Fuels Company is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql responsible for contracts to acquire nuclear materials, except for fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fabrication, for these non-utility nuclear plants. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Based upon currently planned fuel cycles, Entergy's nuclear units \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql currently have contracts and inventory that provide adequate materials \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and services. Existing contracts for uranium concentrate, conversion of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the concentrate to uranium hexafluoride, and enrichment of the uranium \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql hexafluoride will provide a significant percentage of these materials and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql services over the next several years. Additional materials and services \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql required beyond the coverage of these contracts are expected to be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql available at a reasonable cost for the foreseeable future. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Current fabrication contracts will provide a significant percentage \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of these materials and services over the next several years. The Nuclear \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Waste Policy Act of 1982 provides for the disposal of spent nuclear fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql or high level waste by the DOE. There is a discussion of spent nuclear \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel disposal in Note 9 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql It will be necessary for Entergy to enter into additional \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql arrangements to acquire nuclear fuel in the future. It is not possible \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to predict the ultimate cost of such arrangements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, and System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Energy each have made arrangements to lease nuclear fuel and related \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql equipment and services. The lessors finance the acquisition and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ownership of nuclear fuel through credit agreements and the issuance of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql notes. These arrangements are subject to periodic renewal. There is a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql discussion of nuclear fuel leases in Note 10 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Natural Gas Purchased for Resale \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans has several suppliers of natural gas. Its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql system is interconnected with three interstate and three intrastate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql pipelines. Entergy New Orleans' primary suppliers currently are Enron \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql North America, Inc., an interstate gas marketer, Bridgeline Gas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Distributors, and Pontchartrain Natural Gas via Louisiana Gas Services. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans has a "no-notice" service gas purchase contract with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Enron North America, Inc. which guarantees Entergy New Orleans gas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql delivery at any point after the agreed gas volume has been met. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Enron North America, Inc. gas supply is transported to Entergy New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans pursuant to a transportation service agreement with Koch Gateway \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Pipeline Company (now known as Gulf South Pipeline). This service is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql subject to FERC-approved rates. Entergy New Orleans has firm contracts \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with its two intrastate suppliers and also makes interruptible spot \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql market purchases. In recent years, natural gas deliveries to Entergy New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans have been subject primarily to weather-related curtailments. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql However, Entergy New Orleans experienced no such curtailments in 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql As a result of the implementation of FERC-mandated interstate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql pipeline restructuring in 1993, curtailments of interstate gas supply \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql could occur if Entergy New Orleans' suppliers failed to perform their \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql obligations to deliver gas under their supply agreements. Gulf South \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Pipeline could curtail transportation capacity only in the event of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql pipeline system constraints. Based on the current supply of natural gas, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and absent extreme weather-related curtailments, Entergy New Orleans does \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql not anticipate any interruptions in natural gas deliveries to its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql customers. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States purchases natural gas for resale under an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql agreement with Mid Louisiana Gas Company. Mid Louisiana Gas Company is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql not allowed to discontinue providing gas to Entergy Gulf States without \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql obtaining FERC approval. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Research \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, and Entergy New Orleans are members of the Electric Power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Research Institute (EPRI). EPRI conducts a broad range of research in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql major technical fields related to the electric utility industry. Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql participates in various EPRI projects based on Entergy's needs and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql available resources. Entergy and its subsidiaries contributed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approximately $5 million in 2000, $6 million in 1999, and $8 million in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1998 to EPRI and other research programs. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql I{\*\bkmkstart item_1_3_17}{\*\bkmkend item_1_3_17}\plain\cf1\f50\fs16\ql tem 2. Properties \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Information regarding the properties of the registrants is included \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in Item 1. "Business - PROPERTY," in this report. \par\pard\plain\fs16 \par\pard\plain\fs16{\*\bkmkstart item_1_3_18}{\*\bkmkend item_1_3_18}\pard\plain\cf1\f50\fs16\ql Item 3. Legal Proceedings \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Details of the registrants' material rate proceedings, environmental \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulation and proceedings, and other regulatory proceedings and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql litigation that are pending or those terminated in the fourth quarter of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 are discussed in Item 1. "Business - RATE MATTERS AND REGULATION," \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in this report. \par\pard\plain\fs16 \par\pard\plain\fs16{\*\bkmkstart item_1_3_19}{\*\bkmkend item_1_3_19}\pard\plain\cf1\f50\fs16\ql Item 4. Submission of Matters to a Vote of Security Holders \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql A special meeting of stockholders of Entergy Corporation was held on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 15, 2000. The following matter was voted on and received the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql specified number of votes for, abstentions, votes withheld (against), and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql broker non-votes: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Approval and adoption of the Agreement and Plan of Merger dated as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of July 30, 2000, among FPL Group, Inc., Entergy, WCB Holding \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Corporation, Ranger Acquisition Corporation, a wholly owned \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql subsidiary of WCB Holding that will merge into FPL Group, and Ring \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Acquisition Corporation, a wholly owned subsidiary of WCB Holding \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that will merge into Entergy: 171,904,096 votes for; 2,024,569 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql votes against; 910,276 abstentions; and broker non-votes are not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql applicable. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql During the fourth quarter of 2000, no matters were submitted to a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql vote of the security holders of Entergy Arkansas, Entergy Gulf States, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, or System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Energy. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql DIRECTORS AND EXECUTIVE OFFICERS OF ENTERGY CORPORATION \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Directors \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Information required by this item concerning directors of Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Corporation is set forth under the heading "Proposal 1--Election of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Directors" contained in the Proxy Statement of Entergy Corporation, (the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql "Proxy Statement"), to be filed in connection with its Annual Meeting of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Stockholders to be held May 11, 2001, ("Annual Meeting"), and is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql incorporated herein by reference. Information required by this item \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql concerning officers and directors of the remaining registrants is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reported in Part III of this document. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Executive Officers \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Name Age Position Period \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql J. Wayne Leonard 50 Chief Executive Officer and Director 1999-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a) of Entergy Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Director of Entergy Arkansas, Entergy 1998-1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States, Entergy Louisiana, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi, Entergy New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans, and System Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql President and Chief Operating Officer 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Entergy Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Chief Operating Officer of Entergy 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas, Entergy Gulf States, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, and Entergy New Orleans \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Vice Chairman of Entergy New Orleans 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql President of Energy Commodities 1996-1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Strategic Business Unit \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql President of Cinergy Capital & 1996-1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Trading \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Group Vice President and Chief 1994-1996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Financial Officer of Cinergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Corporation \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Donald C. Hintz 58 President of Entergy Corporation 1999-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a) Executive Vice President and Chief 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nuclear Officer of Entergy Arkansas, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States, and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Group President and Chief Nuclear 1997-1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operating Officer of Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Corporation, Entergy Arkansas, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States, and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Executive Vice President and Chief 1994-1997 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nuclear Officer of Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Executive Vice President - Nuclear of 1994-1997 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States, and Entergy Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Chief Executive Officer and President 1992-1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of System Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Director of Entergy Gulf States 1993-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Director of Entergy Arkansas, Entergy 1992-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana, Entergy Mississippi, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Director of Entergy New Orleans 1999-Present \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Jerry D. Jackson 56 Executive Vice President of Entergy 1999-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a) Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Group President - Utility Operations 2000-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Entergy Arkansas, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States, Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, and Entergy New Orleans \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql President and Chief Executive Officer 1999-2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql - Louisiana of Entergy Gulf States \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql President and Chief Executive Officer 1999-2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Entergy Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Chief Administrative Officer of 1997-1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas, Entergy Gulf States, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, and Entergy New Orleans \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Executive Vice President - External 1995-1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Affairs of Entergy Arkansas, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States, Entergy Louisiana, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi, and Entergy New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Executive Vice President - External 1994-1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Affairs of Entergy Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Director of Entergy Gulf States 1994-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Director of Entergy Louisiana 1992-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Director of Entergy Arkansas, Entergy 2000-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, and Entergy New Orleans 1992-1999 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql C. John Wilder 42 Executive Vice President and Chief 1998-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a) Financial Officer of Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Corporation, Entergy Arkansas, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana, Entergy Mississippi, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans, and System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Director of Entergy Arkansas, Entergy 1999-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States, Entergy Louisiana, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi, Entergy New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans, and System Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Chief Executive Officer of Shell 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Capital Company \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Assistant Treasurer of the Royal 1996-1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Dutch/Shell Group \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Director of Economics and Finance of 1995-1996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Shell Exploration and Production \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Frank F. Gallaher 55 Senior Vice President, Generation, 1999-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a) Transmission and Energy Management \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Entergy Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql President, Fossil Operations and 2000-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Transmission of Entergy Arkansas, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana, Entergy Mississippi, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Senior Vice President, Generation, 1999-2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Transmission and Energy Management \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Entergy Arkansas, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States, Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, and Entergy New Orleans \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Executive Vice President and Chief 1998-1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Utility Operating Officer for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States, Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, and Entergy New Orleans \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Group President and Chief Utility 1997-1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operating Officer of Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Group President and Chief Utility 1997-1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operating Officer of Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas, Entergy Gulf States, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, and Entergy New Orleans \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Director of Entergy Arkansas, Entergy 1997-1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana, and Entergy Mississippi \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Executive Vice President of 1996-1997 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operations of Entergy Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql President of Entergy Gulf States 1994-1996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Director of Entergy Gulf States 1993-1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Executive Vice President of 1993-1997 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operations of Entergy Arkansas, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, and Entergy New Orleans \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Richard J. Smith 49 Senior Vice President, Transition 2000-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a) Management of Entergy Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql President of Cinergy Resources, Inc. 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Vice President Energy Services 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Vice President of Finance Services 1996-1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Business Unit \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Executive Director, Budgets and 1989-1996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Forecasts of PSI Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql General Manager, Budgets and 1989-1996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Forecasts of Cinergy \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Michael G. Thompson 60 Senior Vice President and General 1992-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a) Counsel of Entergy Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Senior Vice President, General 1995-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Counsel, and Secretary of Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas, Entergy Gulf States, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, and Entergy New Orleans \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Secretary of Entergy Corporation 1994-Present \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Horace S. Webb 60 Senior Vice President, External 2000-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a) Affairs of Entergy Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Senior Vice President, External 1999-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Affairs of Entergy Services \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Senior Vice President, Public Affairs 1992-1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Consolidated Edison Company \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Joseph T. Henderson 43 Vice President and General Tax 1999-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a) Counsel of Entergy Corporation, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States, Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, Entergy New Orleans, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and System Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Associate General Tax Counsel of 1998-1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Shell Oil Company \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Senior Tax Counsel of Shell Oil 1995-1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Company \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nathan E. Langston 52 Vice President and Chief Accounting 1998-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a) Officer of Entergy Corporation, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States, Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, Entergy New Orleans, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and System Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Director of Tax Services of Entergy 1993-1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Services \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Steven C. McNeal 44 Vice President and Treasurer of 1998-Present \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a) Entergy Corporation, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas, Entergy Gulf States, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, Entergy New Orleans, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and System Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Assistant Treasurer of Entergy 1994-1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas, Entergy Gulf States, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, Entergy New Orleans, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and System Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Director of Corporate Finance of 1994-1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Services \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (a) In addition, this officer is an executive officer and/or director of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql various other wholly owned subsidiaries of Entergy Corporation and its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operating companies. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Each officer of Entergy Corporation is elected yearly by the Board \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Directors. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16{\*\bkmkstart part_1_2_11}{\*\bkmkend part_1_2_11}\pard\plain\cf1\f50\fs16\ql PART II \par\pard\plain\fs16 \par\pard\plain\fs16{\*\bkmkstart item_1_3_20}{\*\bkmkend item_1_3_20}\pard\plain\cf1\f50\fs16\ql Item 5. Market for Registrants' Common Equity and Related Stockholder \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Matters \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The shares of Entergy Corporation's common stock are listed on the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New York Stock, Chicago Stock, and Pacific Exchanges under the ticker \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql symbol ETR. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation's stock price as of February 28, 2001 was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $38.83. The high and low prices of Entergy Corporation's common stock \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for each quarterly period in 2000 and 1999 were as follows: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql High Low High Low \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Dollars) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql First 26.75 15.94 31.13 27.50 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Second 31.25 19.94 33.13 27.75 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Third 38.13 26.94 31.56 28.19 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fourth 43.88 33.50 30.00 23.88 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Consecutive quarterly cash dividends on common stock were paid to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql stockholders of Entergy Corporation in 2000 and 1999. In 2000, dividends \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of $0.30 per share were paid in the first three quarters, and dividends \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of $0.315 per share were paid in the fourth quarter. Quarterly dividends \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of $0.30 per share were paid in 1999. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql As of February 28, 2001, there were 67,226 stockholders of record of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation's future ability to pay dividends is discussed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in Note 8 to the financial statements. In addition to the restrictions \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql described in Note 8, PUHCA provides that, without approval of the SEC, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the unrestricted, undistributed retained earnings of any Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Corporation subsidiary are not available for distribution to Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Corporation's common stockholders until such earnings are made available \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to Entergy Corporation through the declaration of dividends by such \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql subsidiaries. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation, Entergy Arkansas, Entergy Gulf States, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql There is no market for the common stock of Entergy Corporation's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql wholly owned subsidiaries. Cash dividends on common stock paid by the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility companies and System Energy to Entergy Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql during 2000 and 1999, were as follows: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Millions) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas $44.6 $ 82.7 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States $88.0 $107.0 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana $62.4 $197.0 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi $18.0 $ 34.1 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans $ 9.5 $ 26.5 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy $91.8 $ 75.0 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Information with respect to restrictions that limit the ability of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy and the domestic utility companies to pay dividends is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql presented in Note 8 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16{\*\bkmkstart item_1_3_21}{\*\bkmkend item_1_3_21}\pard\plain\cf1\f50\fs16\ql Item 6. Selected Financial Data \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Refer to "SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON OF ENTERGY \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql CORPORATION AND SUBSIDIARIES, ENTERGY ARKANSAS, ENTERGY GULF STATES, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY LOUISIANA, ENTERGY MISSISSIPPI, ENTERGY NEW ORLEANS, and SYSTEM \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENERGY" which follow each company's financial statements in this report, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for information with respect to operating statistics. \par\pard\plain\fs16 \par\pard\plain\fs16{\*\bkmkstart item_1_3_22}{\*\bkmkend item_1_3_22}\pard\plain\cf1\f50\fs16\ql Item 7. Management's Discussion and Analysis of Financial Condition and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Results of Operations \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Refer to "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - LIQUIDITY \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql AND CAPITAL RESOURCES," " - SIGNIFICANT FACTORS AND KNOWN TRENDS," and "- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS OF ENTERGY CORPORATION AND SUBSIDIARIES, ENTERGY \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ARKANSAS, ENTERGY GULF STATES, ENTERGY LOUISIANA, ENTERGY MISSISSIPPI, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY NEW ORLEANS, and SYSTEM ENERGY." \par\pard\plain\fs16 \par\pard\plain\fs16{\*\bkmkstart item_1_3_23}{\*\bkmkend item_1_3_23}\pard\plain\cf1\f50\fs16\ql Item 7A. Quantitative and Qualitative Disclosures About Market Risk \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation and Subsidiaries. Refer to information under \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the heading "ENTERGY CORPORATION AND SUBSIDIARIES MANAGEMENT'S FINANCIAL \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql DISCUSSION AND ANALYSIS - SIGNIFICANT FACTORS AND KNOWN TRENDS." \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16{\*\bkmkstart item_1_3_24}{\*\bkmkend item_1_3_24}\pard\plain\cf1\f50\fs16\ql Item 8. Financial Statements and Supplementary Data. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INDEX TO FINANCIAL STATEMENTS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation and Subsidiaries: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Report of Management 43 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management's Financial Discussion and Analysis 44 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Report of Independent Accountants 64 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management's Financial Discussion and Analysis 65 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Consolidated Statements of Income For the Years Ended December 31, 74 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, 1999, and 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Consolidated Statements of Cash Flows For the Years Ended December 75 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 31, 2000, 1999, and 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Consolidated Balance Sheets, December 31, 2000 and 1999 77 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Consolidated Statements of Retained Earnings, Comprehensive Income, 79 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and Paid-In Capital for the Years Ended December 31, 2000, 1999, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Selected Financial Data - Five-Year Comparison 80 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Inc.: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Report of Independent Accountants 81 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management's Financial Discussion and Analysis 82 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income Statements For the Years Ended December 31, 2000, 1999, and 86 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Statements of Cash Flows For the Years Ended December 31, 2000, 88 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999, and 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Balance Sheets, December 31, 2000 and 1999 89 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Statements of Retained Earnings for the Years Ended December 31, 91 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, 1999, and 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Selected Financial Data - Five-Year Comparison 92 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States, Inc.: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Report of Independent Accountants 93 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management's Financial Discussion and Analysis 94 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income Statements For the Years Ended December 31, 2000, 1999, and 99 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Statements of Cash Flows For the Years Ended December 31, 2000, 100 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999, and 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Balance Sheets, December 31, 2000 and 1999 101 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Statements of Retained Earnings for the Years Ended December 31, 103 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, 1999, and 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Selected Financial Data - Five-Year Comparison 104 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana, Inc.: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Report of Independent Accountants 105 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management's Financial Discussion and Analysis 106 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income Statements For the Years Ended December 31, 2000, 1999, and 109 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Statements of Cash Flows For the Years Ended December 31, 2000, 110 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999, and 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Balance Sheets, December 31, 2000 and 1999 111 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Statements of Retained Earnings for the Years Ended December 31, 113 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, 1999, and 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Selected Financial Data - Five-Year Comparison 114 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi, Inc.: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Report of Independent Accountants 115 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management's Financial Discussion and Analysis 116 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income Statements For the Years Ended December 31, 2000, 1999, and 120 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Statements of Cash Flows For the Years Ended December 31, 2000, 122 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999, and 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Balance Sheets, December 31, 2000 and 1999 123 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Statements of Retained Earnings for the Years Ended December 31, 125 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, 1999, and 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Selected Financial Data - Five-Year Comparison 126 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans, Inc.: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Report of Independent Accountants 127 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management's Financial Discussion and Analysis 128 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income Statements For the Years Ended December 31, 2000, 1999, and 131 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Statements of Cash Flows For the Years Ended December 31, 2000, 132 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999, and 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Balance Sheets, December 31, 2000 and 1999 133 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Statements of Retained Earnings for the Years Ended December 31, 135 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, 1999, and 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Selected Financial Data - Five-Year Comparison 136 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy Resources, Inc.: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Report of Independent Accountants 137 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management's Financial Discussion and Analysis 138 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income Statements For the Years Ended December 31, 2000, 1999, and 140 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Statements of Cash Flows For the Years Ended December 31, 2000, 142 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999, and 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Balance Sheets, December 31, 2000 and 1999 143 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Statements of Retained Earnings for the Years Ended December 31, 145 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, 1999, and 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Selected Financial Data - Five-Year Comparison 146 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Notes to Financial Statements for Entergy Corporation and 147 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Subsidiaries \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql REPORT OF MANAGEMENT \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management of Entergy Corporation and its subsidiaries has prepared \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and is responsible for the financial statements and related financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql information included herein. The financial statements are based on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generally accepted accounting principles in the United States. Financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql information included elsewhere in this report is consistent with the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql To meet their responsibilities with respect to financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql information, management maintains and enforces a system of internal \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accounting controls designed to provide reasonable assurance, on a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cost-effective basis, as to the integrity, objectivity, and reliability \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the financial records, and as to the protection of assets. This \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql system includes communication through written policies and procedures, an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql employee Code of Entegrity, and an organizational structure that provides \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for appropriate division of responsibility and the training of personnel. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql This system is also tested by a comprehensive internal audit program. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The Audit Committee of our Board of Directors, composed solely of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Directors who are not employees of our company, meets with the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql independent auditors, management, and internal accountants periodically \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to discuss internal accounting controls and auditing and financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reporting matters. Upon recommendation from the Audit Committee, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Board of Directors appoints the independent accountants. The Committee \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reviews with the independent auditors the scope and results of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql audit effort. The Committee also meets periodically with the independent \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql auditors and the chief internal auditor without management, providing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql free access to the Committee. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Independent public accountants provide an objective assessment of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the degree to which management meets its responsibility for fairness of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial reporting. They regularly evaluate the system of internal \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accounting controls and perform such tests and other procedures as they \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deem necessary to reach and express an opinion on the fairness of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management believes that these policies and procedures provide \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reasonable assurance that its operations are carried out with a high \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql standard of business conduct. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql J. WAYNE LEONARD C. JOHN WILDER \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Chief Executive Officer of Executive Vice President and Chief \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation Financial Officer \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql HUGH T. MCDONALD JOSEPH F. DOMINO \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Chairman, President, and Chief Chairman of Entergy Gulf States, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Executive Officer of Entergy President and Chief Executive Officer - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas, Inc. Texas of Entergy Gulf States, Inc. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql E. RENAE CONLEY CAROLYN C. SHANKS \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Chairman of Entergy Louisiana, Inc., Chairman, President, and Chief \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql President and Chief Executive Officer Executive Officer of Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql - Louisiana of Entergy Gulf States, Mississippi, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Inc. and Entergy Louisiana, Inc. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql DANIEL F. PACKER JERRY W. YELVERTON \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Chairman, President, and Chief Chairman, President, and Chief \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Executive Officer of Entergy Executive Officer of System Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans, Inc. Resources, Inc. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SIGNIFICANT FACTORS AND KNOWN TRENDS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Business Combination with FPL Group \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql On July 30, 2000, Entergy Corporation and FPL Group entered into a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Merger Agreement providing for a business combination that will result in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the creation of a new company. Each outstanding share of FPL Group common \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql stock will be converted into one share of the new company's common stock, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and each outstanding share of Entergy Corporation common stock will be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql converted into 0.585 of a share of the new company's common stock. It is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expected that FPL Group's shareholders will own approximately 57% of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql common equity of the new company and Entergy's shareholders will own \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approximately 43%. The initial board of directors of the new company will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql consist of eight directors designated by FPL Group and seven directors \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql designated by Entergy. The new company will be given a new name that will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql be agreed upon between the Boards of Directors of FPL Group and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql prior to the consummation of the Merger. The new company will maintain its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql principal corporate offices and headquarters in Juno Beach, Florida, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql will maintain its utility headquarters in New Orleans, Louisiana. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Merger Agreement generally allows Entergy to continue business in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ordinary course consistent with past practice and contains certain \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql restrictions on Entergy's capital activities, including restrictions on the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql issuance of securities, capital expenditures, dispositions, incurrence or \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql guarantee of indebtedness, and trading or marketing of energy. Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generally will be permitted to take actions pursuant to restructuring \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql legislation in the domestic utility companies' jurisdictions of operation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and to reorganize its transmission business. Under certain circumstances, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql if the Merger Agreement is terminated, a termination fee of $215 million \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql may be payable by one of the parties. The Merger Agreement may be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql terminated if the Merger is not consummated by April 30, 2002, unless \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql automatically extended until October 30, 2002 under certain circumstances. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Both the FPL Group and Entergy Boards of Directors unanimously approved the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Merger, and the shareholders of Entergy Corporation and FPL Group have \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approved the Merger. The Merger is conditioned upon, among other things, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the receipt of required regulatory approvals of various local, state, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql federal regulatory agencies and commissions, including the SEC and FERC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy has filed for approval of the Merger in all of its state and local \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulatory jurisdictions (Arkansas, Louisiana, Mississippi, Texas, and New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans), and at FERC, the SEC, and the NRC. In their filing with the SEC, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy and FPL Group requested to remain in existence as intermediate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql holding companies after the Merger is consummated. The objective of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy and FPL Group is to consummate the Merger by late 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Domestic Transition to Competition \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The electric utility industry for years has been preparing for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql advent of competition in its business. For most electric utilities, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transition from a regulated monopoly to a competitive business is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql challenging and complex. The new electric utility environment presents \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql opportunities to compete for new customers and creates the risk of loss of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql existing customers. It presents risks along with opportunities to enter \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql into new businesses and to restructure existing businesses. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For Entergy, the domestic transition to competition is a formidable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql undertaking, made uniquely difficult because the domestic utility companies \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operate in five retail regulatory jurisdictions and are subject to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Agreement, which contemplates the integrated operation of Entergy's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql electric generation and transmission assets throughout the retail service \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql territories. Entergy is striving to achieve consistent paths to competition \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in all five retail regulatory jurisdictions. In some cases, however, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql actions by one jurisdiction may conflict with actions by another. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas and Texas legislatures have enacted laws to bring about electric \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility competition. Entergy is continuing to work with regulatory and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql legislative officials in all jurisdictions in designing the rules \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql surrounding a competitive electricity industry. There can be no assurance \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql given as to the timing or results of the transition to competition in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's service territories. Following is a summary of the status of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transition to competition in the five retail jurisdictions: \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SIGNIFICANT FACTORS AND KNOWN TRENDS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Jurisdiction Status of Retail Open Access % of Entergy's 2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Revenues Derived from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retail Electric Utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operations in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Jurisdiction \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas Commencement delayed by amended 12.3% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql law until at least October 2003. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Texas Scheduled to commence January 1, 9.4% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2002. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana LPSC Staff report due in April 31.4% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2001. The LPSC deferred pursuing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql open access in 1999. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi MPSC has recommended not pursuing 8.0% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql open access at this time. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans City Council has taken no action 4.6% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql on Entergy's proposal filed in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1997. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql State Regulatory and Legislative Activity \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In April 1999, the Arkansas legislature enacted a law providing for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competition in the electric utility industry through retail open access. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql With retail open access, generation operations would become a competitive \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql business, but transmission and distribution operations will continue to be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulated either by federal or state regulatory commissions. In compliance \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with the provisions of the deregulation law, Entergy Arkansas has: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o filed separate generation, transmission, distribution, and customer \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql service rates with the APSC and also filed notice of its intent to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recover stranded costs. In December 2000, the APSC approved the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql unbundled rates as filed. These rates will become effective six months \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql prior to retail open access; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o filed a functional, but not corporate, unbundling plan with the APSC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The functional unbundling plan initially established separate business \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql units for distribution, generation, and a new retail energy service \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql provider. The plan contemplates the transfer of transmission assets \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to the Transco discussed herein. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Note 2 to the financial statements for additional details \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql concerning provisions of the retail open access law. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Texas \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In June 1999, the Texas legislature enacted a law providing for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competition in the electric utility industry through retail open access. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql With retail open access, generation and a new retail electric provider \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operation will be competitive businesses, but transmission and distribution \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operations will continue to be regulated. The new retail electric provider \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql will be the primary point of contact with customers. The provisions of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql new law, among other things: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o require a rate freeze through December 31, 2001 with rates reduced by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 6% beyond that for residential and small commercial customers of most \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql incumbent utilities except Entergy Gulf States, whose rates are exempt \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql from the 6% reduction requirement. These rates to residential and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql small commercial customers are known as the "Price to Beat", and they \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql may be adjusted periodically after January 1, 2002 for fuel and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchased power costs according to PUCT rules; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o require utilities to charge the Price to Beat rates through 2004, or \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql until 40% of customers in the jurisdiction have chosen an alternative \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql supplier, whichever comes first. However, the Price to Beat rates must \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql continue to be made available through 2006. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SIGNIFICANT FACTORS AND KNOWN TRENDS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Pursuant to the provisions of the retail open access law, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States filed a business separation plan with the PUCT in January 2000, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amended that plan in June and December 2000. The plan provides that, by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql January 2002, Entergy Gulf States will be divided into: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a Texas distribution company; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a Texas transmission company; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a Texas generation company; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o at least two Texas retail electricity providers; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a Louisiana company that will encompass distribution, generation, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmission, and retail operations. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The plan also provides that the Louisiana company would retain the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql liability for all debt obligations of Entergy Gulf States and that the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql property of the Texas companies would be released from the lien of Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States' mortgage. Except for the Texas retail electric providers, each \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the Texas companies would assume a portion of Entergy Gulf States' debt \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql obligations, which assumptions would not act to release the Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql company's obligations. Except for the Texas retail electric providers, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql each of the Texas companies would also grant a lien on its properties in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql favor of the Louisiana company to secure its obligations to the Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql company in respect of the assumed obligations. In addition, under the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql plan, Entergy Gulf States will refinance or retire the Texas companies' \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql portion of existing debt by the end of 2004. In July 2000, the PUCT issued \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql an interim order to approve the amended business separation plan. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Regulatory approvals from FERC, the SEC, and the LPSC, and final approval \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql from the PUCT will be required before the business separation plan can be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql implemented. Remaining business separation issues in Texas subsequent to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the July 2000 interim order will be addressed in the cost unbundling \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql proceeding before the PUCT. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The LPSC has opened a docket to identify the changes in corporate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql structure of Entergy Gulf States, and their potential impact on Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql retail ratepayers, resulting from restructuring in Texas and Arkansas. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States filed testimony in that proceeding in August 2000. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LPSC staff filed testimony in that proceeding in October 2000 criticizing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States' proposal, particularly the part related to the Texas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql portion of generation assets being transferred to an unregulated entity. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States filed rebuttal testimony in December 2000. A \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql procedural schedule has not been set. Management cannot predict the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql timing or outcome of this proceeding. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Pursuant to the Texas restructuring legislation, Entergy Gulf States \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql filed its separated business cost data and proposed transmission, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql distribution, and competition tariffs with the PUCT on March 31, 2000. On \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql March 6, 2001, Entergy Gulf States filed with the PUCT a non-unanimous \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql settlement agreement in that case that establishes the distribution \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql revenue requirement. The settlement agreement is between Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States, the PUCT Staff, and other parties. Pursuant to a generic rule \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql prescribed by the PUCT, Entergy Gulf States' allowed return on equity will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql be 11.25%. The generic capital structure prescribed by the PUCT is 60% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql debt and 40% equity. Hearings before the PUCT on approval of the settlement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql are scheduled to begin in April 2001. Management cannot predict the timing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql or outcome of this proceeding. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Beginning January 1, 2002, the market power measures in the open \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql access law will prohibit Entergy Gulf States from owning and controlling \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql more than 20% of the installed generation capacity located in, or capable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of delivering electricity to, a "power region", which is defined as a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql distinct region of NERC. In seeking PUCT approval of the Merger, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and FPL Group are required to demonstrate that the merged company will not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql exceed this threshold. However, all the implications of this limit are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql uncertain for Entergy Gulf States and Entergy. It is possible that Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States could decide to divest some of its generation assets or seek to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reduce transmission constraints if Entergy Gulf States is found to have \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generation market power in excess of this limit. The legislation also \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql requires affected utilities to sell at auction entitlements to at least 15% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of their installed generation capacity in Texas at least 60 days before \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql January 1, 2002. The obligation to auction capacity entitlements continues \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for up to 60 months after January 1, 2002, or until 40% of current \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql customers have chosen an alternative supplier, whichever comes first. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SIGNIFICANT FACTORS AND KNOWN TRENDS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The PUCT and various participants in the industry are currently in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql process of implementing the legislation through various rulemaking and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql other proceedings. The Provider of Last Resort (POLR) rule was approved \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by the PUCT in October 2000, requiring that such a provider exist in every \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql area of the state and setting up the process by which such a provider will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql be selected and its services priced. The PUCT received bids from retail \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql electric providers seeking to become the POLR in each area in January 2001. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The PUCT has stated its preference that the POLR not be the retail electric \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql provider that is affiliated with the incumbent utility in the area. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql However, depending on the outcome of the bidding process, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States' affiliate retail electric provider may be required to provide POLR \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql service in Entergy Gulf States' service territory. This may have a material \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial impact on the Entergy Gulf States retail electric provider \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql depending on the terms and prices eventually approved by the PUCT for POLR \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql service. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Note 2 to the financial statements for additional details concerning \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql provisions of the Texas retail open access law and the proceedings \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql occurring in Texas pursuant to that law. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In March 1999, the LPSC deferred making a decision on whether \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competition in the electric industry is in the public interest. However, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the LPSC staff, outside consultants, and counsel were directed to work \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql together to analyze and resolve issues related to competition and then \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recommend a plan for its implementation to be considered by the LPSC. In \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql January 2001, a draft response was circulated among interested parties. It \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql is expected that, after a comment period, a final staff response will be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql presented to the LPSC in April 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See above under "Texas" for discussion of the LPSC proceeding \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql considering Entergy Gulf States' business separation plan. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In May 2000, after two years of studies and hearings, the MPSC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql announced that it was suspending its docket studying the opening of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql state's retail electricity markets to competition. The MPSC based its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decision on its finding that competition could raise the electric rates \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql paid by residential and small commercial customers. The final decision \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regarding the introduction of retail competition ultimately lies with the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi Legislature, which is holding its 2001 session from January \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql through March. Management cannot predict when, or if, Mississippi will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deregulate its retail electricity market, but does not expect it to occur \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql before 2003. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1997, Entergy New Orleans filed an electric business restructuring \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql plan with the Council. The Council has not established a procedural \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql schedule to consider electricity restructuring or Entergy's plan. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql After studying retail gas open access, advisors to the Council issued \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql a final report that proposed various pilot programs and found that retail \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql gas open access is not in the public interest at this time. The Council \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accepted an offer of settlement from Entergy New Orleans in this matter \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that allows for a voluntary pilot program for a limited number of large \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql industrial non-jurisdictional gas customers. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SIGNIFICANT FACTORS AND KNOWN TRENDS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Federal Regulatory and Legislative Activity \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Proposed System Agreement Amendments \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In June 2000, Entergy's domestic utility companies filed with FERC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql proposed amendments to the System Agreement to facilitate the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql implementation of retail competition in Arkansas and Texas and to provide \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for continued equalization of costs among the domestic utilities in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana and Mississippi. The amendments provide the following: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o cessation of participation in all aspects of the System Agreement, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql other than those related to transmission equalization, for any \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql jurisdictional division of a domestic utility operating in a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql jurisdiction that initiates retail open access; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o certain sections of the System Agreement will no longer apply to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql sales of generating capacity, whether through the sale of the asset \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql or the output thereof, by a domestic utility operating in a jurisdiction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that has established a date by which it will implement retail open \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql access; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o modification of the service schedule developed to track changes in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql energy costs resulting from the Entergy-Gulf States Utilities merger \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to include one final true-up of fuel costs upon cessation of one \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql company's participation in the System Agreement, after which the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql service schedule will no longer be applicable for any purpose. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Previously, in April 2000, the LPSC and the Council filed a complaint \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with FERC seeking revisions to the System Agreement. The LPSC and the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Council allege that the revisions are necessary to accommodate the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql introduction of retail competition in Texas and Arkansas and to protect \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's Louisiana customers from any adverse impact that may occur due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the introduction of retail competition in some jurisdictions but not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql others. The LPSC and the Council requested that FERC cap certain of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Agreement obligations of Entergy Gulf States, Entergy Louisiana, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans and fix these companies' access to pool energy at the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql average level existing for the three years prior to the date that retail \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competition is initiated in Texas and Arkansas. Alternatively, the LPSC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and the Council requested that FERC require Entergy to provide wholesale \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power contracts to these companies to satisfy their energy requirements at \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs no higher than would have been incurred if retail competition were \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql not implemented. The LPSC and the Council requested that the relief be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql made available for at least eight years after implementation of retail \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competition or the withdrawal of Entergy Arkansas and Entergy Gulf States \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql from the System Agreement, or until retail competition is implemented in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana and New Orleans. In addition, among other things, the LPSC and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Council asserted in their complaint that: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o unless the requested relief is granted, the restructuring legislation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adopted in Texas and Arkansas, to the extent such legislation requires, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql or has the effect of, altering the rights of parties under the System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement, will violate provisions of the U.S. Constitution; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the failure of the domestic utility companies to honor a right of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql first refusal at cost with respect to any sale of generating capacity \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and associated energy under the System Agreement, and any attempt to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql eliminate a right of first refusal from the System Agreement, would \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql violate the Federal Power Act and constitute a breach of the System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SIGNIFICANT FACTORS AND KNOWN TRENDS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The proceedings relating to Entergy's proposed amendments have been \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql consolidated with the complaint by the LPSC and the Council. Several other \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql parties have also intervened in the proceedings. If FERC considers \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's proposed amendments, the LPSC and the Council have asserted that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FERC also needs to reconsider the charges to the domestic utility companies \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql under the Unit Power Sales Agreement. Entergy has requested a final \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decision from FERC by October 2001. A procedural schedule has been \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql established, with the hearing beginning in March 2001 and an initial ALJ \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decision scheduled in June 2001. These proceedings have been consolidated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with a previous complaint filed with FERC by the LPSC in 1995. In that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql complaint, the LPSC requests, among other things, modification of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Agreement to exclude curtailable load from the cost allocation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql determination. Neither the timing, nor the ultimate outcome of these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql proceedings at FERC, can be predicted at this time. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Open Access Transmission and Entergy's Transco Proposal \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FERC issued Order 2000 in December 1999, which calls for owners and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operators of transmission lines in the United States to join regional \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmission organizations (RTOs) on a voluntary basis. Order 2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql requires that RTOs commence independent operations no later than December \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 15, 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql It appears that FERC will be flexible regarding the structure of RTOs. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For example, it appears that RTOs may be for-profit or not-for-profit and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql may be organized as joint ventures or legal entities of various other \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql types. However, RTOs will be required, among other things, to be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql independent market participants, to have sufficient regional scope to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql maintain reliability and efficiency, to be non-discriminatory in granting \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql service, and to maintain operational control over their regional \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmission systems. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In October 2000, in compliance with Order 2000, Entergy made a filing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with FERC that requested: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o authorization to establish an RTO referred to as Transco; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o authorization to transfer the domestic utility companies' transmission \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql assets to the Transco; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a determination that the partnership arrangement with the Southwest \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Power Pool (SPP) that the Transco proposes to operate in would qualify \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql as an independent RTO. The partnership arrangement provides for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operations under the oversight of, and within, the SPP RTO. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The amounts of the domestic utility companies' net transmission utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql plant assets recorded in their financial statements are provided in Note 1 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to the financial statements under the heading "Utility Plant." \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The proposed Transco will be a limited liability company. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql managing member of the Transco will be a separate corporation with a board \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of directors independent of Entergy. The Transco will be: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o regulated by FERC; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o composed of the transmission system transferred to it by the domestic \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility companies and other transmission owners in Entergy's current \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql service territory region; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o operated and maintained by employees who would work exclusively for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Transco and would not be employed by Entergy or the domestic \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility companies; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o passively owned by the domestic utility companies and other member \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies who will transfer assets but not control or otherwise direct \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql its operation and management. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SIGNIFICANT FACTORS AND KNOWN TRENDS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy filed in December 2000 for FERC approval of the rates for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmission service across the Transco's facilities. Included in this \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rate filing is a request to cancel the service schedule in the System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement related to equalization of certain transmission costs. In March \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2001, Entergy, Entergy Services, and the domestic utility companies \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql requested SEC approval under PUHCA of certain elements of the Transco plan. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The domestic utility companies have also made filings with their local \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulators seeking authorization to implement the Transco plan. Under its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql planned timeline, Entergy expects to have the necessary regulatory \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approvals by the third quarter of 2001, with the transmission asset \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transfers occurring before Transco commences independent operations in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deregulation legislation \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Over the past several years, a number of bills have been introduced in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the United States Congress to deregulate the generation function of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql electric power industry. The bills generally have provisions that would \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql give retail consumers the ability to choose their own electric service \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql provider. Entergy Corporation has supported some deregulation legislation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in Congress that would lead to an orderly transition to competition and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql would also repeal PUHCA and PURPA. Congressional sentiment appears to be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql against mandating retail competition by a certain date and in favor of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql clarifying state authority to order retail choice for consumers. Congress \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adjourned in 2000 without final action on a deregulation bill by a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql committee of the House or Senate, and has not taken final action on such a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql bill in its 2001 session thus far. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Industrial and Commercial Customers \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The domestic utility companies face the risk of losing customers due \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to competition. Some of their large industrial and commercial customers \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql are exploring ways to reduce their energy costs. In particular, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cogeneration is an option available to a significant portion of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility companies' industrial customer base. The domestic utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies have responded by working with some industrial and commercial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql customers and negotiating electric service contracts that provide service \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql at rates lower than would otherwise be charged. Despite these actions, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States and Entergy Louisiana have lost an immaterial amount of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operating income in recent years from large industrial customers who have \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql completed cogeneration projects. Material losses to cogeneration are not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expected in 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql State and Local Rate Regulation \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The retail regulatory basis for setting rates for electric service is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql shifting in some jurisdictions from traditional, exclusively cost-of- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql service regulation to include performance-based elements. Performance- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql based formula rate plans are designed to reward increased efficiency and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql productivity, with utility shareholders and customers sharing in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql benefits. Entergy Mississippi and Entergy Louisiana have implemented \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql performance-based rate plans. Entergy Mississippi's 2000 filing indicated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that no change in rate levels was warranted. Entergy Louisiana and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States had the following rate activity in 2000: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Filing Rate Activity Implementation Date \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana 4th annual $6.4 million refund July 2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql performance-based rate plan \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana 5th annual $24.8 million base August 2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql performance-based rate plan rate reduction* \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States 2nd, 3rd, $83 million refund, July to September 2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 4th, and 5th annual earnings including interest \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reviews \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SIGNIFICANT FACTORS AND KNOWN TRENDS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql * Entergy Louisiana is proposing to increase prospectively the allowed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rate of return on common equity from 10.5% to 11.6%, which, if approved by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the LPSC, would reduce the amount of the rate reduction. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The domestic utility companies' retail and wholesale rate matters and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql proceedings are discussed more thoroughly in Note 2 to the financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other Electric Utility Trends \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In some areas of the country, utilities have either sold or are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql attempting to sell all or a substantial portion of their generation assets \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in order to focus their businesses on transmission and/or distribution \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql services. Entergy, through its global power development and domestic non- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility nuclear businesses, intends to expand its generation business. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql While the global power development business is focused on building new \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power plants or modifying existing plants, the nuclear business expansion \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql plan focuses on acquiring generation assets of other utilities. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1998, California implemented electricity deregulation legislation. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The law required the major investor-owned utilities in the state to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql effectively divest their generation assets by requiring them to sell their \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql output to the Power Exchange. The Power Exchange is an independent spot \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql market power pool in which electricity is bought and sold at wholesale \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql prices. The deregulation law requires the investor-owned utilities to buy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power from the Power Exchange at market set rates, but freezes the amount \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that those utilities can recover from their customers. Therefore, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql investor-owned utilities' short positions were not covered by generation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql assets and were exposed to increases in the Power Exchange prices. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql jurisdictions in which Entergy's domestic utility companies operate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql currently allow recovery of all prudently incurred fuel and purchased power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs through various recovery mechanisms. In addition, the deregulation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql legislation enacted in Arkansas and Texas allows for adjustments to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql prices that the distribution businesses will be allowed to recover based on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql changes in fuel and purchased power costs. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, the California Power Exchange prices that the California \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql investor-owned utilities have to pay for their electricity supplies soared \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql above the amounts that they are allowed to recover from their customers. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The California utilities therefore have accumulated billions of dollars of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql under-recovered purchased power expenses. These under-recovered costs have \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql caused the California utilities to default on certain of their credit \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql obligations and have spawned several lawsuits and legislative and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulatory activity. The ultimate effect of these events on the investor- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql owned utilities in California and the electric energy industry nationwide \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql is uncertain. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Continued Application of SFAS 71 and Stranded Cost Exposure \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The domestic utility companies' and System Energy's financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements primarily reflect assets and costs based on existing cost-based \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ratemaking regulation in accordance with SFAS 71, "Accounting for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Effects of Certain Types of Regulation." Under traditional ratemaking \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql practice, regulated electric utilities are granted exclusive geographic \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql franchises to sell electricity. In return, the utilities must make \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql investments and incur obligations to serve customers. Prudently incurred \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs are recovered from customers along with a return on investment. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Regulators may require utilities to defer collecting from customers some \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operating costs until a future date. These deferred costs are recorded as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulatory assets in the financial statements. In order to continue \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql applying SFAS 71 to its financial statements, a utility's rates must be set \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by an independent regulator on a cost-of-service basis and the rates must \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql be charged to and collected from customers. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SIGNIFICANT FACTORS AND KNOWN TRENDS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql As the generation portion of the utility industry moves toward \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competition, it is likely that generation rates will no longer be set on a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cost-of-service basis. When that occurs, the generation portion of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql business could be required to discontinue application of SFAS 71. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql result of discontinuing application of SFAS 71 could be the recording of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql asset impairments and the removal of regulatory assets and liabilities from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the balance sheet. This result is because some of the costs or commitments \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql incurred under a regulated pricing system might be impaired or not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovered in a competitive market. These costs are referred to as stranded \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nearly all of Entergy's exposure to potential stranded costs involves \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commitments that were approved by regulators. These exposures include the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql following: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the allowed cost of constructing its nuclear generating plants (the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility companies' net investment in nuclear generation is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql provided in Note 1 to the financial statements); \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o long-term contracts to purchase power under the Unit Power Sales \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement and associated with the Vidalia project, which may require \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql paying above-market prices in a competitive environment (detail \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql concerning these obligations is provided in Note 9 to the financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements); \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o nuclear power plant decommissioning costs (detail concerning these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs is provided in Note 9 to the financial statements); \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the construction cost of some fossil-fueled generating plants and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql related contracts to buy fuel that may be above-market price in a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competitive market (detail concerning the domestic utility companies' \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql net investment in generation other than nuclear, which is primarily \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fossil fueled, is provided in Note 1 to the financial statements, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and detail concerning certain fuel contracts is provided in Note 9 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to the financial statements); and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o regulatory assets reflected in the balance sheets. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql As of December 31, 2000, the amount of these potentially strandable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs for Entergy reflected in the financial statements is approximately \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $1.8 billion at Entergy Arkansas, $3.2 billion at Entergy Gulf States, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $2.4 billion at Entergy Louisiana, and $0.3 billion at Entergy Mississippi. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The estimated net present value of the obligations described above that are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql not reflected in the financial statements for Entergy is approximately $1.0 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql billion at Entergy Arkansas, $0.3 billion at Entergy Gulf States, $1.5 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql billion at Entergy Louisiana, $0.6 billion at Entergy Mississippi, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $0.3 billion at Entergy New Orleans. These amounts can increase due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increased capital spending; however, in the normal course of business, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql depreciation, amortization, and payments under the contractual obligations \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql should reduce these amounts. The actual amount of these costs and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql obligations that will be identified as stranded will be determined in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulatory proceedings. The outcome of the proceedings cannot be predicted \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and will depend upon a number of variables, including the timing of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql stranded cost determination, the values attributable to certain strandable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql assets, assumptions concerning future market prices for electricity, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql other factors. In addition, because transition legislation or regulation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql is not in place in Louisiana, Mississippi, or New Orleans, Entergy cannot \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql predict how those jurisdictions will treat stranded costs and whether \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy will be able to recover all or a part of the costs in those \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql jurisdictions. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SIGNIFICANT FACTORS AND KNOWN TRENDS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In June 2000, Entergy Arkansas filed an application to continue the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql stranded cost mitigation efforts agreed upon in the 1997 settlement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql agreement approved by the APSC. The filing included a stranded cost \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql estimate intended to support Entergy Arkansas' recommendation that the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql mitigation efforts continue. The filing presents an estimated range of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql stranded costs based upon the comparison of possible generation asset \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql market values to the generation assets' book values and contractual \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql obligations. The range of possible generation asset market values used in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the estimate was determined using generation asset sales from other \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql jurisdictions. Rebuttal testimony filed by Entergy Arkansas in November \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 estimates that stranded costs in Arkansas could be from $227.8 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million to $1.58 billion. The wide range in the estimate is because of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the wide range in the comparable asset sales used in the estimate. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In the non-unanimous settlement agreement filed with the PUCT by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States in March 2001, the parties agree that Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States will not implement a charge to recover stranded costs in Texas. A \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rider to recover nuclear decommissioning costs will be implemented. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Hearings before the PUCT for approval of the settlement are scheduled to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql begin in April 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management believes that definitive outcomes have not yet been \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql determined regarding the transition to competition in each of Entergy's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql jurisdictions. Arkansas and Texas have enacted retail open access laws as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql described above, but Entergy believes that significant issues remain to be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql addressed by Arkansas and Texas regulators, and the enacted laws do not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql provide sufficient detail to determine definitively the impact on Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas' and Entergy Gulf States' regulated operations. Until the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulatory proceedings in Arkansas and Texas provide a greater level of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql certainty, both Entergy Arkansas and Entergy Gulf States will continue to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql apply SFAS 71 to their regulated operations. Final approval of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql settlement agreement in Texas will likely result in Entergy Gulf States \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql discontinuing application of SFAS 71 to its Texas generation operations. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SFAS 71 will continue to be applied in the Louisiana, Mississippi, and New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans jurisdictions pending legislative or regulatory developments \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql relating to transition to competition. If SFAS 71 is no longer applied by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the respective domestic utility companies and System Energy, and regulation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql or legislation does not allow for recovery of all or a portion of its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql stranded costs, there could be a material adverse impact on the respective \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility companies' and Entergy's financial statements. The impact \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of approval of the Texas settlement agreement will depend upon a final \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql determination of the market value of generation assets in Texas. Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql believes that the amount of costs that will be stranded without a means of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovery or mitigation for the domestic utility companies will be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql significantly less than the strandable cost amounts given above. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql specifics of the accounting application of SFAS 71 are discussed more \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql thoroughly in Note 1 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Market Risks Disclosure \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy is exposed to the following market risks: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the commodity price risk associated with its power marketing and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql trading business; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the interest rate risk associated with certain of its variable rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql credit facilities; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the foreign currency exchange rate risk associated with certain of its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contractual obligations; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the interest rate and equity price risk associated with its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql investments in decommissioning trust funds. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SIGNIFICANT FACTORS AND KNOWN TRENDS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's power marketing and trading business enters into sales and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchases of electricity and natural gas for delivery in the future. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Because the market prices of electricity and natural gas can be volatile, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's power marketing and trading business is exposed to risk arising \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql from differences between the fixed prices in its commitments and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fluctuating market prices. To mitigate its exposure, Entergy's power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql marketing and trading business enters into electricity and natural gas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql futures, swaps, option contracts, and electricity forward agreements. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql business also manages its exposure with policies limiting its exposure to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql market risk and daily monitoring of its potential financial exposure. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's power marketing and trading business uses a value-at-risk \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql model (VAR) as one measure of the market risk of a loss in fair value for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the traded portfolio. VAR acts in conjunction with stress testing, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql position reporting, and profit and loss reporting in order to measure and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql control the risk inherent in the traded portfolio. The primary use of VAR \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql is to provide a benchmark for market risk contained in the trading \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql portfolio. VAR does not function as a comprehensive measure of all risks \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in a portfolio. Furthermore, VAR is only an appropriate risk measure for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql products traded in relatively liquid markets. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management's VAR methodology uses a variance/covariance approach to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the measurement of market risk. The variance/covariance approach assumes \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that prices follow a "random-walk" process in which prices are lognormally \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql distributed. This approach requires the following inputs: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a one-tailed test with a 95% confidence interval that measures the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql probability of loss; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a 20-day window for measuring volatility; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a cross-product correlation matrix that measures the tendency of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql different basis products to move together; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an inter-temporal correlation matrix that measures the tendency of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commodities with different delivery periods to move together. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Power marketing and trading's VAR was approximately $2.9 million as of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, 2000 and $3.3 million as of December 31, 1999. During 2000, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the average month-end VAR was $4.2 million, with a high month-end VAR of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $8.5 million and a low month-end VAR of $2.5 million. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management's calculation of VAR exposure represents an estimate of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reasonably possible net losses that would be recognized on its portfolio of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql derivative financial instruments, assuming hypothetical movements in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql prices. It does not represent the maximum possible loss or an expected \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql loss that may occur, because actual future gains and losses will differ \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql from those estimated based upon actual fluctuations in market rates, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operating exposures, and the timing thereof, and changes in the portfolio \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of derivative financial instruments during the year. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In November 2000, System Fuels and Entergy's domestic non-utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql nuclear business entered into foreign currency forward contracts to hedge \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Euro denominated payments due under certain purchase contracts. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql notional amounts of the foreign currency forward contracts were 82.8 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million Euro ($73.2 million) and the forward currency rates range from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql .8690 to .8981. The maturities of these forward contracts depend on the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contractual payment dates and range in time from August 2001 to February \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2004. The mark-to-market valuation of the forward contracts at December \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 31, 2000 was a net asset of $5.9 million. The counterparty banks obligated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql on these agreements are rated by Standard and Poor's Rating Services at A-1 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql or above on their short-term obligations and AA- on their long-term \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql obligations. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SIGNIFICANT FACTORS AND KNOWN TRENDS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy uses interest rate swaps to reduce the impact of interest rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql changes on certain variable-rate credit facilities associated with its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql global power development business. Under the interest rate swap \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql agreements, Entergy receives floating-rate interest payments and pays fixed- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rate interest rate payments over the life of the agreements. The floating- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rate interest that Entergy receives is approximately equal to the interest \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql it must pay on the variable-rate credit facilities. Therefore, through the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql use of the swap agreements, Entergy effectively achieves a fixed rate of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql interest on the credit facilities. The following details information about \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the interest rate swaps as of December 31, 2000: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Average \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Notional Fixed Maturity Fair value \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Amount Pay Rate \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Saltend $443.3 million 6.44% 2013 ($16.6 million) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Damhead Creek $414.5 million 6.52% 2010 ($18.4 million) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy is exposed to fluctuations in equity prices and interest rates \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql through its nuclear decommissioning trust funds. The NRC requires Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to maintain trusts to fund the costs of decommissioning ANO 1, ANO 2, River \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Bend, Waterford 3, Grand Gulf, and Pilgrim. The funds are invested \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql primarily in equity securities; fixed-rate, fixed-income securities; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cash and cash equivalents. Management believes that its exposure to market \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fluctuations will not affect results of operations for the ANO, River Bend, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Grand Gulf, and Waterford 3 trust funds because of the application of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulatory accounting principles. The Pilgrim trust fund holds \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approximately $314 million of fixed-rate, fixed-income securities as of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, 2000. These securities have an average coupon rate of 6.7%, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql an average duration of 5.8 years, and an average maturity of 8.8 years. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The Pilgrim trust fund also holds equity securities worth approximately \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $116 million as of December 31, 2000. These securities are held in a fund \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that is designed to approximate the Standard & Poor's 500 Index. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decommissioning trust funds are discussed more thoroughly in Notes 1 and 9 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Accounting Pronouncement \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In June 1998, the FASB issued SFAS 133, "Accounting for Derivative \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Instruments and Hedging Activities," which will be implemented by Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in 2001. See Note 1 to the financial statements for a discussion of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expected effect of this pronouncement on Entergy. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LIQUIDITY AND CAPITAL RESOURCES \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash Flow \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operations \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow from operations for Entergy, the domestic utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies, and System Energy for the years ended December 31, 2000, 1999, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and 1998 was: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Millions) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy $1,967.8 $1,389.0 $1,835.7 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas $ 421.6 $ 352.6 $ 448.7 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States $ 403.9 $ 387.6 $ 491.3 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana $ 270.4 $ 410.4 $ 342.4 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi $ 182.3 $ 142.4 $ 125.0 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans $ 30.5 $ 60.2 $ 40.3 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy $ 395.6 $ 102.8 $ 298.8 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's consolidated cash flow from operations increased in 2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql primarily due to the domestic utility companies and System Energy providing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql an additional $277.5 million and the competitive businesses providing an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql additional $223.7 million to operating cash flows for the year ended \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel cost recovery activity in 2000 significantly affected the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operating cash flows for the domestic utility companies. Historically high \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql natural gas and purchased power costs in 2000 caused the domestic utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies' fuel payments to increase significantly during the year. In the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql case of Entergy Arkansas, the Texas portion of Entergy Gulf States, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi, the 2000 under-recoveries have been treated as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulatory investments in the cash flow statements because those companies \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql are allowed by their regulatory jurisdictions to recover the fuel costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accumulated in 2000 over longer than a twelve month period, and the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies will earn a return on the under-recovered balances. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas' and Entergy Gulf States' operating cash flows were \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql also affected by increases in their net income for the year ended December \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 31, 2000. The increase in operating cash flow for Entergy Gulf States was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql partially offset by the increased use of cash for fuel costs related to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana jurisdiction and refunds of $83 million paid to Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql customers during the third quarter of 2000 as a result of earnings reviews \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql settled with the LPSC, as discussed further in Note 2 to the financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements. The decrease in operating cash flow for Entergy Louisiana and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans was partially caused by the increased use of cash \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql related to fuel costs in 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The operating cash flows of the domestic utility companies and System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Energy were affected by money pool activity for 2000 as a result of the use \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of a portion of the proceeds from debt issuances in 2000 to pay down \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql payables to the money pool in the following amounts: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas $ 9.9 million \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States $36.1 million \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana $91.5 million \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi $16.7 million \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans $ 3.9 million \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LIQUIDITY AND CAPITAL RESOURCES \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy's operating cash flow increased in part due to payments of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $78.9 million received on its money pool receivables from affiliated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The money pool is an inter-company funding arrangement designed to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reduce the domestic utility companies' and System Energy's dependence on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql external short-term borrowings. The money pool provides a means by which, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql on a daily basis, the excess funds of Entergy Corporation, the domestic \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility companies, and System Energy may be used by the domestic utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies or System Energy to fulfill short-term cash requirements. See \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql "Capital Resources - Sources of Capital" below for a discussion of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql limitations on these borrowings. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The increase in operating cash flow for the competitive businesses is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql attributable to the following: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the operations of Pilgrim, Indian Point 3, and FitzPatrick that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql primarily caused an increase of $73.9 million in operating cash flow \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql from the domestic non-utility nuclear business; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o net income generated by and improved operations in the power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql marketing and trading and global power development businesses in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, which resulted in an additional $40.2 million and $91.0 million \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of operating cash flow, respectively, compared with net losses from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql their operations in 1999. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Pilgrim was purchased in July 1999 and provided operating cash flow for all \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of 2000 compared with only six months in 1999. Indian Point 3 and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FitzPatrick were purchased in November 2000 and provided operating cash \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql flow for two months in 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's consolidated cash flow from operations for 1999 decreased as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql compared to 1998 primarily due to less cash provided by competitive \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql businesses. The decrease was also due to the completion of rate phase-in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql plans for some of the domestic utility companies during 1998. Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States' Louisiana retail phase-in plan for River Bend was completed in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql February 1998, Entergy Mississippi's phase-in plan for Grand Gulf 1 was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql completed in September 1998, and Entergy Arkansas' phase-in plan for Grand \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf 1 was completed in November 1998. Therefore, these phase-in plans did \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql not contribute to operating cash flow in 1999 or 2000. Entergy New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans' phase-in plan for Grand Gulf 1 will be completed in 2001. System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Energy's operating cash flow decreased in 1999 primarily due to an increase \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in its money pool receivables from affiliated companies. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, competitive businesses used $9.3 million of operating cash \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql flow from operations compared with providing $151.7 million of operating \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cash flow for 1998. This change was primarily due to the sales of London \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Electricity and CitiPower in December 1998. Both businesses contributed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operating cash flow in 1998 but did not contribute at all in 1999. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Offsetting the decrease in operating cash flow in 1999 were the sales of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Efficient Solutions, Inc. in September 1998 and Entergy Security, Inc. in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql January 1999. These businesses used operating cash flow in 1998 and used \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql none in 1999. Also, the power marketing and trading business used less \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operating cash flow in 1999 than in 1998. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Investing Activities \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash used in investing activities increased for 2000 due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increased construction expenditures, decreased proceeds from sales of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql businesses, decreased net proceeds from maturities of notes receivable, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql higher fuel costs. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The increased construction expenditures were primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o spending on customer service and reliability improvements by the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility companies; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o costs incurred related to the December 2000 ice storms, primarily at \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o costs incurred for replacement of the steam generators at ANO 2. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LIQUIDITY AND CAPITAL RESOURCES \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The following items also contributed to the overall increase in cash \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql used in 2000: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the maturity of notes receivable in August 1999 when only a portion of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the proceeds were reinvested in other temporary investments; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o payments made by Entergy's global power development business in 2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for turbines; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the under-recovery of deferred fuel costs incurred in 2000 at certain \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the domestic utility companies due to significantly higher market \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql prices of fuel and purchased power expenses. Entergy Arkansas, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Texas portion of Entergy Gulf States, and Entergy Mississippi have \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql treated these costs as regulatory investments because those companies \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql are allowed by their regulatory jurisdictions to recover the fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cost regulatory asset accumulated in 2000 over longer than a twelve \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql month period, and the companies will earn a return on the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql under-recovered balances. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Partially offsetting the overall increase in cash used is the maturity of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql other temporary investments and proceeds from the sale of the Freestone \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power project in 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Investing activities used cash in 1999 compared to 1998 due to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql sales in 1998 of London Electricity and CitiPower, and higher construction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expenditures in 1999 compared with 1998. The increased construction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expenditures were primarily due to construction of the Saltend and Damhead \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Creek power plants by Entergy's global power development business, spending \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql on customer service and reliability improvements by the domestic utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies, and the return to service of generation plants at Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas, Entergy Louisiana, and Entergy New Orleans. The maturity and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reinvestment of a portion of the proceeds of notes receivable in August \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999, and the sales in 1999 of Entergy Security, Entergy Power Edesur \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Holding, LTD and several other telecommunications businesses partially \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql offset the overall decrease in 1999. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Financing Activities \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Financing activities provided cash for 2000 primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o new long-term debt issuances by Entergy Arkansas, Entergy Gulf States, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased borrowings under the Entergy Corporation credit facility. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Partially offsetting the overall cash provided were the following in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased repurchases of Entergy Corporation common stock; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o redemption of Entergy Gulf States' preference stock; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o decreased borrowings under the credit facilities for the construction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the Saltend and Damhead Creek power projects by Entergy's global \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power development business. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash used in financing activities decreased in 1999 compared to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1998 primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the retirement in 1998 of debt associated with the acquisition of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql London Electricity and CitiPower; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased borrowings in 1999 under the credit facilities for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql construction of the Saltend and Damhead Creek power plants by Entergy's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql global power development business; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a reduction in dividend payments made by Entergy Corporation in 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql compared to 1998. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LIQUIDITY AND CAPITAL RESOURCES \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Partially offsetting the 1999 overall decrease were the following \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql uses: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the 1999 repayment of bank borrowings by Entergy Corporation and ETHC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with a portion of the proceeds from the sale of Entergy Security, Inc.; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the redemption of preferred stock in 1999 at Entergy Arkansas, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States, and Entergy Louisiana; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the repurchase of Entergy Corporation common stock. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Capital Resources \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's sources to meet its capital requirements include: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o internally generated funds; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o cash on hand; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o debt or preferred stock issuances; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o common stock issuances; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o bank financing under new or existing facilities; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o short-term borrowings; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o sales of assets. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy requires capital resources for: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o working capital purposes, including the financing of fuel and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchased power costs; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o construction and other capital expenditures; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o debt and preferred stock maturities; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o common stock repurchases; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o capital investments; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o funding of subsidiaries; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o dividend and interest payments. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sources of Capital \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql All of the domestic utility companies issued new debt in 2000. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql net proceeds of these issuances have been or will be used for general \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql corporate purposes including capital expenditures, the retirement of short- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql term indebtedness incurred for working capital or other purposes, and, in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the case of Entergy Gulf States, the mandatory redemption of preference \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql stock. The domestic utility companies and System Energy expect to continue \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql refinancing or redeeming higher cost debt and preferred stock prior to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql maturity, to the extent market conditions and interest and dividend rates \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql are favorable. The domestic utility companies plan to issue debt in 2001 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for similar purposes as in 2000. In addition, rising fuel prices in 2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and the resulting increases in the domestic utility companies' fuel costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql have increased these companies' needs for working capital financing in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2001. Entergy Arkansas' liquidity was also affected by incurring \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approximately $195 million of restoration costs associated with ice storms \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in December 2000. See Note 2 to the financial statements for more \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql information regarding the December 2000 ice storms. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LIQUIDITY AND CAPITAL RESOURCES \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql All debt and common and preferred stock issuances by the domestic \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility companies and System Energy require prior regulatory approval. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred stock and debt issuances are subject to issuance tests set forth \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in corporate charters, bond indentures, and other agreements. The domestic \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility companies have sufficient capacity under these issuance tests to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql consummate the financings planned for 2001. The domestic utility companies \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql may also establish special purpose trusts or limited partnerships as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financing subsidiaries for the purpose of issuing preferred securities. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql On January 31, 2001, Entergy Mississippi issued $70 million of 6.25% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Series First Mortgage Bonds due February 1, 2003. Proceeds of the issuance \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql will be used for general corporate purposes, including the retirement of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql short-term indebtedness incurred from money pool borrowings for capital \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expenditures and working capital needs. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql On February 23, 2001, Entergy New Orleans issued $30 million of 6.65% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Series First Mortgage Bonds due March 1, 2004. Proceeds of the issuance \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql will be used for general corporate purposes, including the retirement of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql short-term indebtedness incurred from money pool borrowings for capital \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expenditures and working capital needs. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Entergy Louisiana, and Entergy Mississippi each \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql obtained 364-day credit facilities in 2001, and the lines have been fully \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql drawn. Entergy Arkansas will primarily use the proceeds to pay for costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql incurred in the December 2000 ice storms. Entergy Louisiana and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi will use the proceeds for general corporate purposes and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql working capital needs. The facilities have variable interest rates and the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql average commitment fee is 0.13%. The amounts and dates obtained for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql facilities follow: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Amount of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Company Facility Date Obtained \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas $ 63 million January 31, 2001 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana $ 30 million January 31, 2001 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi $ 25 million February 2, 2001 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2001, Entergy, Entergy Mississippi, and Entergy New Orleans \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql requested an increase from the SEC in their current authorized short-term \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql borrowing limits, which includes borrowings under the money pool. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increases requested are as follows: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Company Current Limit Requested Limit \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi $ 103 million $ 160 million \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans $ 35 million $ 100 million \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other Entergy subsidiaries $ 265 million $ 420 million \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SEC approval of the request will increase the current SEC authorized short- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql term borrowing limits for the domestic utility companies and System Energy, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql which are effective through November 30, 2001, from $1.078 billion to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $1.2 billion. Note 4 to the financial statements contains details of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amount of short-term indebtedness outstanding for Entergy, the domestic \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility companies, and System Energy as of December 31, 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, long-term debt on Entergy's balance sheet were increased by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approximately $750 million by the issuance of notes payable to NYPA in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Indian Point 3 and FitzPatrick acquisition. Also in 2000, the global power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql development business increased its borrowings under the Damhead Creek \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql credit facility by approximately $164 million to finance construction of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the plant. Damhead Creek commenced commercial operation in 2001. Note 7 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to the financial statements more thoroughly discusses these long-term debts. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LIQUIDITY AND CAPITAL RESOURCES \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Uses of Capital \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the years 2001 through 2003, Entergy plans to spend $8.2 billion \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in a capital investment plan focused on improving service at the domestic \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility companies and growing its global power development and domestic non- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility nuclear businesses. The estimated allocation in the plan is $2.6 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql billion to the domestic utility companies, $3.6 billion to the global power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql development business, and $2.0 billion to the domestic non-utility nuclear \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql business. Management provides more information on construction expenditures \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and long-term debt and preferred stock maturities in Notes 5, 6, 7, and 9 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The capital investment plan discussed above is subject to modification \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql based on the ongoing effects of transition to competition planning, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ability to recover the regulated utility costs in rates, and the proposed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql business combination with FPL Group. The Merger Agreement generally allows \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy to continue business in the ordinary course consistent with past \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql practice and contains certain restrictions on Entergy's activities, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql including restrictions on the issuance of securities, capital expenditures, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql dispositions, incurrence or guarantee of indebtedness, and trading or \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql marketing of energy. Entergy does not believe that these covenants will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql constrain its capital investment plan. Under certain circumstances, if the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Merger Agreement is terminated, a termination fee of $215 million may be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql payable by one of the parties. Additionally, the plan is contingent upon \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the ability to access the capital necessary to finance the planned \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expenditures, and significant borrowings may be necessary to implement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql these capital spending plans. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PUHCA Restrictions on Uses of Capital \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's ability to invest in domestic and foreign generation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql businesses is subject to the SEC's regulations under PUHCA. Absent SEC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approval, these regulations limit Entergy Corporation's aggregate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql investment in domestic and foreign generation businesses at the time an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql investment is made to an amount equal to 50% of average consolidated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql retained earnings for the previous four quarters. In June 2000, the SEC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql issued an order that allows Entergy's EWG and FUCO investments to increase \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql from 50% to 100% of Entergy's average consolidated retained earnings. As \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of December 31, 2000 Entergy's investments subject to this rule totaled \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $770 million constituting 25% of its average consolidated retained \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql earnings. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's ability to guarantee obligations of its non-utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql subsidiaries is also limited by SEC regulations under PUHCA. In August \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, the SEC issued an order, effective through December 31, 2005, that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql allows Entergy to issue up to $2 billion of guarantees to its non-utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies, excluding guarantees outstanding as of that date that were \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql issued under a previous order. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Under PUHCA, the SEC imposes a limit equal to 15% of consolidated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql capitalization on the amount that may be invested in "energy-related" \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql businesses without specific SEC approval. Entergy has made investments in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql energy-related businesses, including power marketing and trading. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's available capacity to make additional investments at December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 was approximately $1.8 billion. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LIQUIDITY AND CAPITAL RESOURCES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other Uses of Capital by Entergy Corporation \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Under the terms of the Merger Agreement, Entergy will use its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commercially reasonable efforts to purchase in open market transactions \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $430 million of its common stock prior to the close of the Merger. As of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, 2000, Entergy has repurchased 4.2 million shares for an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql aggregate amount of $145.6 million after the signing of the Merger \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement. Prior to the date of the Merger Agreement, Entergy had been \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql repurchasing shares under two Board authorizations. In October 1998, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Board approved a plan for the repurchase of Entergy common stock through \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, 2001 to fulfill the requirements of various compensation and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql benefit plans. This stock repurchase plan provided for open market \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchases of up to 5 million shares for an aggregate consideration of up to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $250 million. In July 1999, the Board approved the commitment of up to an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql additional $750 million for the repurchase of Entergy common stock through \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, 2001. Shares were repurchased on a discretionary basis. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Prior to the date of the Merger Agreement, Entergy had repurchased 25.3 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million shares for an aggregate amount of $652.5 million under these two \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Board authorizations. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, Entergy Corporation paid $271.0 million in cash dividends on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql its common stock and received dividend payments and returns of capital \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql totaling $918.3 million from subsidiaries. Declarations of dividends on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's common stock are made at the discretion of the Board. The Board \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql evaluates the level of Entergy common stock dividends based upon Entergy's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql earnings and financial strength. Dividend restrictions are discussed in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Note 8 to the financial statements. Under the Merger Agreement, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql can continue to pay dividends at existing levels with increases permitted \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql up to 5% over the amount of the previous twelve-month period. In October \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 and January 2001, the Board declared quarterly dividends of $0.315 per \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql share on Entergy's common stock. This dividend level is an increase of 5% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql over the dividend level for the twelve-month period prior to the Merger \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Agreement. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Global Power Development Business \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Included in the capital investment plan for Entergy's global power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql development business are payments under an option it obtained in October \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999 to acquire twenty-four GE7FA advanced technology gas turbines, four \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql steam turbines, and eight GE7EA advanced technology gas turbines. In the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql sale of the Freestone power project in June 2000, Entergy sold the rights \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to acquire four of the GE7EA turbines and two of the steam turbines. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deliveries of the remaining turbines are scheduled for 2001 through 2004. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management plans to use the turbines in future generation projects of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql global power development business, and anticipates that the acquisition of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the turbines will be funded by a combination of cash on hand, project \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financing, and other external financing. In addition, management expects \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that up to $225 million of the turbine acquisitions will be supported by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation guarantees. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, Entergy's global power development business began \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql construction of the Warren Power Project, a 300 MW combined-cycle gas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql turbine merchant power plant in Vicksburg, Mississippi. The construction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs are expected to be approximately $150 million. Management expects \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that commercial operation of the plant will begin in the summer of 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Domestic Non-Utility Nuclear Business \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In November 2000, Entergy's domestic non-utility nuclear business \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchased NYPA's 825 MW James A. FitzPatrick nuclear power plant located \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql near Oswego, New York and NYPA's 980 MW Indian Point 3 nuclear power plant \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql located in Westchester County, New York. Entergy paid NYPA $50 million in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cash at the closing of the purchase, and will pay seven annual installments \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of approximately $108 million commencing one year from the date of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql closing, and eight annual installments of $20 million commencing eight \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql years from the date of the closing. Entergy currently projects that these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql installments will be paid primarily from the proceeds of the sale of power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql from the plants and that Entergy will provide an additional $100 million of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql funding. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LIQUIDITY AND CAPITAL RESOURCES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Pursuant to the terms of the agreement with NYPA, the installment \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql payments due by Entergy to NYPA must be secured by a letter of credit from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql an eligible financial institution. On November 21, 2000, upon closing of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the acquisition of the NYPA plants, Entergy delivered a $577 million letter \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of credit, with NYPA as beneficiary, in accordance with the terms of such \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql agreement. The letter of credit was backed by cash collateral, and this \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cash is reflected in the balance sheet as "Special deposits." In February \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2001, Entergy replaced $440 million of the cash collateral with an Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Corporation guarantee. Most of the cash released by this guarantee was used \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to fund Entergy's cash contribution made for its interest in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy/Koch Industries joint venture discussed below under "Joint \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Ventures." \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Included in the domestic non-utility nuclear business' capital \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql investment plan is the acquisition of Consolidated Edison's (Con Edison) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 957 MW Indian Point 2 nuclear power plant (IP2) located in Westchester \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql County, New York. In November 2000, Entergy's domestic non-utility nuclear \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql business signed an agreement with Con Edison to purchase the plant. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy will pay $600 million in cash at the closing of the purchase and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql will receive the plant, nuclear fuel, and other assets, including a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchase power agreement (PPA). The financing of the purchase may require \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the support of an Entergy Corporation guarantee. On the second anniversary \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the IP2 acquisition, Entergy's domestic non-utility nuclear business \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql will also begin to pay NYPA $10 million per year for up to 10 years in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accordance with the Indian Point 3 purchase agreement. Under the PPA, Con \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Edison will purchase 100% of IP2's output through 2004. Con Edison will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql also transfer a $430 million decommissioning trust fund, along with the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql liability to decommission IP2 and Indian Point 1, to Entergy's domestic non- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility nuclear business. Management expects to close the acquisition by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql mid-2001, pending the approvals of the NRC, the New York Public Service \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Commission, and other regulatory agencies. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Joint Ventures \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql On January 31, 2001, subsidiaries of Entergy and Koch Industries, Inc. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql formed a new limited partnership called Entergy-Koch, L.P. Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contributed its power marketing and trading business in the United States \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and the United Kingdom and made other contributions, including equity and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql loans, totaling $414 million. Koch Energy, Inc. contributed to the venture \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql its 9,000-mile Koch Gateway Pipeline, gas storage facilities including the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Bistineau storage facility near Shreveport, Louisiana, and Koch Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Trading, which markets and trades electricity, gas, weather derivatives and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql other energy-related commodities and services. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's global power development business has a 50% interest in RS \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cogen LLC, a joint venture with PPG Industries. In August 2000, RS Cogen \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LLC completed a $242 million non-recourse financing for a 425 MW natural \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql gas-fired, combined-cycle power plant, known as the Riverside project. In \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql September 2000, construction of the plant began at estimated construction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs approximately equal to the amount of the financing arrangement. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Management expects that commercial operation of the plant will begin in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2002. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LIQUIDITY AND CAPITAL RESOURCES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation and System Energy \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Pursuant to an agreement with certain creditors, Entergy Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql has agreed to supply System Energy with sufficient capital to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o maintain System Energy's equity capital at a minimum of 35% of its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql total capitalization (excluding short-term debt); \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o permit the continued commercial operation of Grand Gulf 1; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o pay in full all System Energy indebtedness for borrowed money when \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o enable System Energy to make payments on specific System Energy debt, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql under supplements to the agreement assigning System Energy's rights in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the agreement as security for the specific debt. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The Capital Funds Agreement and other Grand Gulf 1-related agreements \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql are more thoroughly discussed in Note 9 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Report of Independent Accountants \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql To the Board of Directors and Shareholders of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation: \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In our opinion, the accompanying consolidated balance sheets and the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql related consolidated statements of income, of retained earnings, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql comprehensive income and paid-in-capital and of cash flows (pages 74 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql through 79 and pages 147 through 209) present fairly, in all material \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql respects, the financial position of Entergy Corporation and its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql subsidiaries at December 31, 2000 and 1999, and the results of their \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operations and their cash flows for each of the three years in the period \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ended December 31, 2000 in conformity with accounting principles generally \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accepted in the United States of America. These financial statements are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the responsibility of the Company's management; our responsibility is to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql express an opinion on these financial statements based on our audits. We \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql conducted our audits of these statements in accordance with auditing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql standards generally accepted in the United States of America, which require \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that we plan and perform the audit to obtain reasonable assurance about \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql whether the financial statements are free of material misstatement. An \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql audit includes examining, on a test basis, evidence supporting the amounts \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and disclosures in the financial statements, assessing the accounting \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql principles used and significant estimates made by management, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql evaluating the overall financial statement presentation. We believe that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql our audits provide a reasonable basis for our opinion. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PricewaterhouseCoopers LLP \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans, Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql February 1, 2001 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's consolidated earnings applicable to common stock were $679.3 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million for the year ended December 31, 2000 resulting in increases in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql basic and diluted earnings per share of 33% and 32%, respectively. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increase in earnings per share was also affected by Entergy's share \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql repurchase program. Entergy's consolidated earnings applicable to common \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql stock were $552.5 million for the year ended December 31, 1999 resulting in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql a decrease in basic and diluted earnings per share of 25% compared with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1998. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The changes in earnings applicable to common stock by operating \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql segments for 2000 and 1999 as compared to the prior year are as follows: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Increase/(Decrease) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operating Segments 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Domestic Utility and System Energy $ 75,684 $ 29,020 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Power Marketing & Trading 20,133 15,049 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Domestic Non-Utility Nuclear 33,453 16,768 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Global Power Development 46,246 (23,550) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy London and CitiPower - (120,852) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other, including parent company (48,681) (103,045) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- --------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total $126,835 $(186,610) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ======== ========= \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other for 1998 included the results of operations for Efficient \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Solutions, Inc., Entergy Security, Inc., Entergy Power Edesur \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Holdings, and several telecommunications businesses that were sold \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql between late 1998 and mid-1999. It also included the gains on the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1998 sales of Entergy London and CitiPower. See Note 14 to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial statements for additional business segment information. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The increase in 2000 earnings at the domestic utility companies and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy was primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in energy usage by customers; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in revenues as a result of a warmer than normal spring and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql summer and a colder than normal winter; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a decrease of $21.4 million in interest and other charges; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a decrease of $45.5 million in reserves recorded in 2000 for potential \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rate actions; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a $10.9 million decrease in preferred dividend requirements primarily \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to the retirement of Entergy Gulf States' preference stock. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The increases were partially offset by: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase of $95.8 million in operation and maintenance expense; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase of $44.5 million in depreciation and amortization expense; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase of $23.5 million in taxes other than income taxes; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in the effective income tax rate. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The increase at the power marketing and trading business in 2000 was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o improved trading performance in electricity; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased long-term marketing of electricity; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o trading gains in natural gas in the current year due to natural gas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql prices reaching record high levels compared to trading losses in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql prior year. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The increase at the domestic non-utility nuclear business in 2000 was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql primarily due to the ownership of Pilgrim for the entire year compared to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql only six months in 1999, and the increase for 1999 was due to the purchase \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Pilgrim in July 1999. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The increase at the global power development business in 2000 was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql primarily due to $55.1 million of liquidated damages received from the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Saltend contractor as compensation for lost operating margin from the plant \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to construction delays. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other decreased in 2000 primarily due to the write-down of Entergy's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql investments in Latin America to their fair market values. Other decreased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in 1999 primarily due to the non-recurring gains recorded on business sales \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in 1998. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's income before taxes is discussed in two business categories, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql "Domestic Utility Companies and System Energy" and "Competitive \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Businesses". Competitive Businesses primarily includes power marketing and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql trading, domestic non-utility nuclear, global power development, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql several businesses that were sold in 1998 and 1999. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Domestic Utility Companies and System Energy \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The changes in electric operating revenues for Entergy's domestic \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility companies for 2000 and 1999 are as follows: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Increase/(Decrease) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Description 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Millions) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Base revenues ($94.2) $81.2 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Rate riders (17.1) (164.1) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel cost recovery 792.5 188.7 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales volume/weather 107.1 5.3 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other revenue (including unbilled) 135.8 74.3 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales for resale 24.2 (50.3) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------ ------ \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total $948.3 $135.1 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ====== ====== \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Base revenues \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Base revenues decreased in 2000 primarily due to the non-recurring \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql effect on 1999 revenues of the reversal of regulatory reserves associated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with the accelerated amortization of accounting order deferrals discussed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql below. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, base revenues increased primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a $93.6 million reversal in June 1999 of regulatory reserves \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql associated with the accelerated amortization of accounting order \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deferrals in conjunction with the settlement agreement in Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States' Texas 1996 and 1998 rate filings. The settlement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql agreement was approved by the PUCT in June 1999. The net income \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql effect of this reversal is largely offset by the amortization of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rate deferrals discussed below; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a reduction in the amount of reserves recorded in 1999 at Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States compared to 1998 for the anticipated effects of rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql proceedings in Texas. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Partially offsetting these increases were: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o annual base rate reductions implemented for Entergy Gulf States' \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana and Texas retail customers in 1998 and 1999 and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi customers in 1999; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o reserves recorded by Entergy Gulf States related to the Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql jurisdiction, Entergy Louisiana, and Entergy New Orleans in 1999 for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql potential rate actions or rate refunds. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Rate riders \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Rate rider revenues do not impact earnings since specific incurred \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expenses offset them. In 1999, rate rider revenues decreased $164.1 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million due to a revised Grand Gulf rider implemented at Entergy Arkansas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and Entergy Mississippi, resulting in a corresponding decrease in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amortization of rate deferrals. The revised rider eliminated revenues \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql attributable to the Grand Gulf phase-in plans, which were completed in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1998, and implemented the Grand Gulf Accelerated Recovery Tariff (GGART), \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql allowing accelerated recovery and payment of a portion of the two \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies' Grand Gulf purchased power obligations. The tariffs became \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql effective in January 1999 and October 1998, respectively. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel cost recovery \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The domestic utility companies are allowed to recover certain fuel and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchased power costs through fuel mechanisms included in electric rates \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that are recorded as fuel cost recovery revenues. The difference between \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql revenues collected and current fuel and purchased power costs is recorded \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql as deferred fuel costs on Entergy's financial statements such that these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs generally have no net effect on earnings. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel cost recovery revenues increased in 2000 primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased fuel recovery factors at Entergy Arkansas, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States in the Texas jurisdiction, and Entergy Mississippi; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o higher fuel and purchased power costs at Entergy Louisiana and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans due to the increased market price of natural gas. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Along with the increase in fuel cost recovery revenue, fuel and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchased power expenses increased by $794.2 million in 2000 primarily due \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in the market prices of purchased power, natural gas, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel oil; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in volume due to an increase in demand. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The increase in fuel and purchased power expenses was partially offset by a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $23.5 million adjustment to the Entergy Arkansas deferred fuel balance to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql record deferred fuel costs that Entergy Arkansas expects to recover in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql future through its fuel adjustment clause. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, fuel cost recovery revenues increased primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increased fuel factor and a new fuel surcharge implemented by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States in the Texas jurisdiction in 1999; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o recovery of higher-priced fuel and purchased power costs at Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana due to nuclear outages at Waterford 3 in 1999; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in the energy cost recovery rate effective April 1999 and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the completion of a customer refund obligation in 1998 which lowered \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1998 fuel cost recovery at Entergy Arkansas. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, fuel and purchased power expenses increased due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o higher natural gas and purchased power prices as well as increased gas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql usage at Entergy Arkansas and Entergy Louisiana; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o higher fuel recovery due to an increased fuel factor and fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql surcharge in Entergy Gulf States' Texas jurisdiction; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increased energy cost recovery rate in 1999 and the completion of a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql customer refund obligation in 1998 which lowered 1998 fuel cost \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovery at Entergy Arkansas. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql These increases were partially offset by decreased fuel expenses at Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi as a result of lower total generation. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other effects on revenue \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Electric operating revenues also increased in 2000 due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased sales volume due to increased usage by industrial, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commercial, and residential customers; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased sales due to weather conditions in 2000; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased generation and subsequent sales from River Bend in 2000 as a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql result of a refueling outage in 1999; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o higher fuel prices included in unbilled revenues. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Electric sales vary seasonally in response to weather, and usually \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql peak in the summer. The effect of colder than normal winter weather \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql conditions in 2000 contributed to the increase in electric sales. In 2000, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql electricity sales volume in the domestic utility companies' service \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql territories increased 1,522.7 GWH due to the impact of weather conditions. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Electric sales volume also increased 1,173.9 GWH due to higher demand by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql industrial, commercial, and residential customers. The number of customers \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in the domestic utility companies' service territories remained constant \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql during these periods. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Electric operating revenues also increased in 1999 primarily due to a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql change in estimated unbilled revenues, which more closely aligned the fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql component of unbilled revenues with regulatory treatment. This increase \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql was partially offset by a decline in sales for resale due to the loss of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql certain municipal and co-op customer contracts at Entergy Arkansas. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other operation and maintenance expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other operation and maintenance expenses increased $95.8 million in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased property insurance expenses of $22.8 million primarily due \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to storm damage accruals related to the December 2000 ice storms at \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas and due to changes in storm damage reserve \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amortization at Entergy Arkansas, Entergy Louisiana, and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi in accordance with regulatory treatment; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased customer service expenses of $11.4 million primarily related \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to spending on vegetation management at Entergy Arkansas; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased nuclear expenses of $17.2 million primarily from Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas and Entergy Gulf States; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase of $28.4 million primarily due to an increase in legal and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contract expenses for the transition to retail open access at Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas and Entergy Gulf States and for legal services employed for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rate-related proceedings at Entergy Louisiana; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase of $21.9 million in plant maintenance expense primarily at \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The increase in other operation and maintenance expenses in 2000 was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql partially offset by the following: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a $9.5 million larger nuclear insurance refund in 2000 compared to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a decrease in injury and damages claims of $12.3 million. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, other operation and maintenance expenses increased $68.3 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased customer service and reliability improvements throughout the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql system; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increases in storm damage accruals, employee pension and benefits, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql environmental expenses; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increases in maintenance work at Entergy Arkansas and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation and amortization \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation and amortization expenses increased $44.5 million in 2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the review of plant-in-service dates for consistency with regulatory \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql treatment that reduced depreciation expense by $17.7 million in August \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased depreciation of $14.0 million associated with the principal \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql payment on the sale and leaseback of Grand Gulf 1; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o net capital additions primarily at Entergy Louisiana and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, depreciation and amortization expenses decreased $32.8 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o lower depreciation at Entergy Gulf States as a result of the write- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql down of the River Bend abeyed plant as required by the Texas rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql settlement and a review of plant in-service dates; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o reduction in principal payments associated with the sale and leaseback \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in 1989 of a portion of Grand Gulf 1 at System Energy. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory charges \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, other regulatory charges decreased due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o lower accruals for transition costs in 1999 at Entergy Arkansas; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a change in the amortization period for deferred River Bend finance \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql charges in the Entergy Gulf States' Texas retail jurisdiction; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o deferral of Year 2000 costs at Entergy Gulf States and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana in accordance with an LPSC order. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql These decreases were partially offset by increased charges at System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Energy as a result of the implementation of the GGART at Entergy Arkansas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and Entergy Mississippi. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest charges \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest charges decreased $21.4 million in 2000 primarily due to an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adjustment in 1999 at System Energy to the interest recorded for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql potential refund to customers of its proposed rate increase pending at \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FERC. System Energy's proposed rate increase is discussed in Note 2 to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, interest charges decreased due to the retirement and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql refinancing of long-term debt, partially offset by the interest recorded on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the potential refund of System Energy's proposed rate increase. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Competitive Businesses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The changes in operating revenues for the competitive businesses by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operating segments in 2000 and 1999 are as follows: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Increase/(Decrease) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Millions) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Power Marketing & Trading $(117.9) $(605.7) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Domestic Non-Utility Nuclear 188.4 104.6 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Global Power Development 201.4 0.1 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy London and CitiPower - (2,215.1) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other (16.9) (108.2) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------ --------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total $255.0 $(2,824.3) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ====== ========= \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The decrease in 2000 for the power marketing and trading business \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql results from decreased electricity and gas trading volumes. Although \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql revenues decreased, the power marketing and trading business had an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increase in operating income for the year ended December 31, 2000, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o decreased purchased power expenses as discussed below; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o improved trading performance in electricity; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased long-term marketing of electricity; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o trading gains in natural gas in the current year due to natural gas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql prices reaching record high levels compared to trading losses in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql prior year. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The decrease in 1999 for the power marketing and trading business \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql resulted primarily from decreased electricity trading volume due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql significantly warmer weather in 1998 than in 1999. However, the impact on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql net income from these decreased revenues was more than offset by decreased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel and purchased power expenses as discussed below, resulting in a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql smaller operating loss for this business for the year ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999 as compared to 1998. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The increase in 2000 for the domestic non-utility nuclear business was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql primarily from the operation of the Pilgrim, Indian Point 3, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FitzPatrick plants. Pilgrim was purchased in July 1999 and Indian Point 3 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and FitzPatrick were purchased in November 2000. The increase in 1999 for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the domestic non-utility nuclear business was primarily from the operation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Pilgrim. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The increase in 2000 for the global power development business was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql primarily due to the results from its interest in Highland Energy, which \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql was acquired in June 2000, and the results from the Saltend plant, which \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql began commercial operation in late November 2000. However, the impact on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql net income from increased revenues from the global power development \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql business is offset by increased fuel and purchased power as discussed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql below. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The decrease in 1999 for Entergy London and CitiPower was due to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql sale of these businesses in 1998. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel and purchased power expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel costs constitute the largest expense for the competitive \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql businesses. Fuel and purchased power expenses increased $20.4 million in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, primarily due to Highland Energy's operations and increased expenses \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for the domestic non-utility nuclear business from Pilgrim contributing for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql all of 2000 compared with only six months in 1999, along with the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql acquisition of Indian Point 3 and FitzPatrick in November 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Partially offsetting the overall increase in 2000 in fuel and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchased power expenses is the decrease of $206.9 million from the power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql marketing and trading business attributable to decreased electricity and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql gas trading volumes. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel and purchased power expenses decreased in 1999 primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the sales of London Electricity and CitiPower; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o decreased electricity trading volume in the power marketing and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql trading business; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a $44 million ($27 million net of tax) counterparty default incurred \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in 1998 by the power marketing and trading business. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql These decreases were partially offset by increased gas trading volume in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the power marketing and trading business. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other operation and maintenance expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other operation and maintenance expenses increased $98.6 million in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 primarily from the operation of Pilgrim for all of 2000 compared with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql only six months in 1999, partially offset by a decrease in the elimination \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of mark-to-market profits on intercompany power transactions. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other operation and maintenance expenses decreased $349.7 million in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999 primarily due to the sales of London Electricity and CitiPower. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decrease was partially offset by: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase for the power marketing and trading business resulting \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql primarily from increased risk management and back-office support; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase for the domestic non-utility nuclear business resulting \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql primarily from the operation of Pilgrim for six months in 1999. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other income \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other income decreased $38.5 million for the year ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 primarily due to a $42.5 million ($27.6 million net of tax) write-down \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in 2000 to their estimated fair values of investments in Latin American \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql projects. The decrease is also due to the absence of the following items \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that occurred in 1999: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a $26.7 million ($17 million net of tax) gain on the sale of Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Power Edesur Holdings in June 1999; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a $12.9 million ($8 million net of tax) gain on the sale of Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Hyperion Telecommunications in June 1999; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a $22.0 million ($6.4 million net of tax) gain on the sale of Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Security, Inc. in January 1999, including a true-up recognized in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 1999; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a $7.6 million ($4.9 million net of tax) favorable adjustment to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql final sale price of CitiPower in January 1999; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a more favorable experience on warranty reserves in 1999 for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql businesses sold during 1998. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Partially offsetting the overall decrease was the following in 2000: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o liquidated damages of $55.1 million ($38.6 million net of tax) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql received from the Saltend contractor as compensation for lost operating \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql margin from the Saltend plant due to construction delays; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase of $16.2 million in interest and dividend income; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a $20.5 million ($13.3 million net of tax) gain in June 2000 on the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql sale of the global power development business' investment in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Freestone project located in Fairfield, Texas. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other income decreased in 1999 primarily due to the gains recorded in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1998 on the sales of Entergy London of $327.3 million ($246.8 million net \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of tax) and CitiPower of $29.8 million ($19.3 million net of tax). The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decrease in 1999 was partially offset by the following: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o interest income of $58.5 million in 1999 on the proceeds of the sales \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Entergy London and CitiPower; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o gains on sales of businesses in 1999, as listed above; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a $68.6 million ($35.9 million net of tax) loss on the sale of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Efficient Solutions, Inc. (formerly Entergy Integrated Solutions, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Inc.) in September 1998; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o $32.8 million ($21.3 million net of tax) of write-downs of Entergy's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql investments in two Asian projects in 1998; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o favorable experience on warranty reserves for the businesses sold \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql during 1998. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest charges \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other interest charges increased $29.0 million in 2000 primarily due \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the accretion of the decommissioning liability associated with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Pilgrim; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased interest expense of $16.0 million related to borrowings on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation's short-term credit facility. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The effective income tax rates for 2000, 1999, and 1998 were 40.3%, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 37.5%, and 25.3%, respectively. The increase in 2000 was primarily due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the recognition in 1999 of deferred tax benefits related to the expected \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utilization of foreign tax credits resulting in lower income taxes. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The effective income tax rate increased in 1999, partially offset by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the recognition of foreign tax credits discussed above, primarily due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the following in 1998: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the recognition of $44 million of deferred tax benefits in 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql related to expected utilization of Entergy's capital loss \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql carryforwards; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a $31.7 million reduction in taxes because of reductions in the UK \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql corporation tax rate from 31% to 30% in the third quarter of 1998. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql CONSOLIDATED STATEMENTS OF INCOME \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands, Except Share Data) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING REVENUES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Domestic electric $7,219,686 $6,271,414 $6,136,322 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Natural gas 165,872 110,355 115,355 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Steam products - 15,852 43,167 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Competitive businesses 2,630,590 2,375,607 5,199,928 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ----------- ---------- ----------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 10,016,148 8,773,228 11,494,772 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ----------- ---------- ----------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING EXPENSES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operating and Maintenance: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel, fuel-related expenses, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql gas purchased for resale 2,645,835 2,082,875 1,706,028 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Purchased power 2,662,881 2,442,484 4,585,444 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nuclear refueling outage expenses 70,511 76,057 83,885 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other operation and maintenance 1,901,314 1,705,545 1,988,040 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Decommissioning 39,484 45,988 46,750 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Taxes other than income taxes 370,344 339,284 362,153 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation and amortization 746,125 698,881 938,179 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory charges - net 3,681 14,833 35,136 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Amortization of rate deferrals 30,392 115,627 237,302 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ----------- ---------- ----------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 8,470,567 7,521,574 9,982,917 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ----------- ---------- ----------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING INCOME 1,545,581 1,251,654 1,511,855 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ----------- ---------- ----------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OTHER INCOME \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for equity funds used during construction 32,022 29,291 12,465 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gain (loss) on sale of assets - net (20,466) 71,926 274,941 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Miscellaneous - net 190,129 154,423 85,618 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ----------- ---------- ----------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 201,685 255,640 373,024 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ----------- ---------- ----------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INTEREST AND OTHER CHARGES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest on long-term debt 477,071 476,877 735,601 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other interest - net 85,635 82,471 65,047 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Distributions on preferred securities of subsidiaries 18,838 18,838 42,628 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for borrowed funds used during construction (24,114) (22,585) (10,761) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ----------- ---------- ----------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 557,430 555,601 832,515 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ----------- ---------- ----------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INCOME BEFORE INCOME TAXES 1,189,836 951,693 1,052,364 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes 478,921 356,667 266,735 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ----------- ---------- ----------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql CONSOLIDATED NET INCOME 710,915 595,026 785,629 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred dividend requirements and other 31,621 42,567 46,560 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ----------- ---------- ----------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql EARNINGS APPLICABLE TO \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql COMMON STOCK $679,294 $552,459 $739,069 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql =========== ========== =========== \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Earnings per average common share: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Basic $3.00 $2.25 $3.00 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Diluted $2.97 $2.25 $3.00 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Dividends declared per common share $1.22 $1.20 $1.50 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Average number of common shares outstanding: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Basic 226,580,449 245,127,460 246,396,469 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Diluted 228,541,307 245,326,883 246,572,328 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql CONSOLIDATED STATEMENTS OF CASH FLOWS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql OPERATING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Consolidated net income $710,915 $595,026 $785,629 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Noncash items included in net income: \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Amortization of rate deferrals 30,392 115,627 237,302 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Reserve for regulatory adjustments 18,482 10,531 130,603 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Other regulatory charges - net 3,681 14,833 35,136 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Depreciation, amortization, and decommissioning 785,609 744,869 984,929 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Deferred income taxes and investment tax credits 124,457 (189,465) (64,563) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Allowance for equity funds used during construction (32,022) (29,291) (12,465) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql (Gain) loss on sale of assets - net 20,466 (71,926) (274,941) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Changes in working capital (net of effects from acquisitions and dispositions): \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Receivables (437,146) 9,246 24,176 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Fuel inventory (20,447) (1,359) 28,439 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Accounts payable 543,606 35,233 31,229 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Taxes accrued 20,871 158,733 58,505 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Interest accrued 45,789 (56,552) (37,937) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Deferred fuel (38,001) 10,583 63,991 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Other working capital accounts 102,336 45,285 43,209 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Provision for estimated losses and reserves 6,019 (59,464) (133,880) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Changes in other regulatory assets (66,903) (36,379) (13,684) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Other 149,743 93,494 (49,996) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ---------- ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Net cash flow provided by operating activities 1,967,847 1,389,024 1,835,682 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql INVESTING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Construction/capital expenditures (1,493,717) (1,195,750) (1,143,612) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Allowance for equity funds used during construction 32,022 29,291 12,465 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Nuclear fuel purchases (121,127) (137,649) (102,747) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Proceeds from sale/leaseback of nuclear fuel 117,154 137,093 128,210 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Proceeds from sale of businesses 61,519 351,082 2,275,014 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Investment in other nonregulated/nonutility properties (238,062) (81,273) (85,014) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Proceeds from other temporary investments 321,351 956,356 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Purchase of other temporary investments - (321,351) (947,444) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Decommissioning trust contributions and realized change in trust assets (63,805) (61,766) (73,641) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Other regulatory investments (385,331) (81,655) (82,984) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Other (44,016) (42,258) - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ---------- ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Net cash flow used in investing activities (1,814,012) (447,880) (19,753) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql See Notes to Financial Statements. \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql CONSOLIDATED STATEMENTS OF CASH FLOWS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FINANCING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Proceeds from the issuance of: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term debt 904,522 1,113,370 1,904,074 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Common stock 41,908 15,320 19,341 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retirement of: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term debt (181,329) (1,195,451) (3,151,680) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Repurchase of common stock (550,206) (245,004) (2,964) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Redemption of preferred stock (157,658) (98,597) (17,481) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Changes in short-term borrowings - net 267,000 (165,506) 205,412 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Dividends paid: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Common stock (271,019) (291,483) (373,441) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred stock (32,400) (43,621) (46,809) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow provided by (used in) financing activities 20,818 (910,972) (1,463,548) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Effect of exchange rates on cash and cash equivalents (5,948) (948) 1,567 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net increase in cash and cash equivalents 168,705 29,224 353,948 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and cash equivalents at beginning of period 1,213,719 1,184,495 830,547 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and cash equivalents at end of period $1,382,424 $1,213,719 $1,184,495 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ========== ========== ========== \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash paid during the period for: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest - net of amount capitalized $505,414 $601,739 $833,728 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes $345,361 $373,537 $273,935 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Noncash investing and financing activities: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Change in unrealized appreciation/(depreciation) of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decommissioning trust assets ($11,577) $41,582 $46,325 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Decommissioning trust fund acquired in Pilgrim acquisition - $428,284 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Acquisition of Indian Point 3 and FitzPatrick \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fair value of assets acquired $917,667 - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Initial cash paid at closing $50,000 - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Liabilities assumed and notes issued to seller $867,667 - - \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql CONSOLIDATED BALANCE SHEETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ASSETS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql CURRENT ASSETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Cash and cash equivalents: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Cash $157,550 $108,198 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Temporary cash investments - at cost, \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql which approximates market 640,038 1,105,521 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Special deposits 584,836 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------- ----------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total cash and cash equivalents 1,382,424 1,213,719 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------- ----------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other temporary investments - at cost, \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql which approximates market - 321,351 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Notes receivable 3,608 2,161 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accounts receivable: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Customer 497,821 290,331 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Allowance for doubtful accounts (9,947) (9,507) \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 395,518 213,939 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accrued unbilled revenues 415,409 298,616 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------- ----------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total receivables 1,298,801 793,379 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------- ----------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Deferred fuel costs 568,331 240,661 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Fuel inventory - at average cost 93,679 73,231 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Materials and supplies - at average cost 425,357 392,403 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Rate deferrals 16,581 30,394 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Deferred nuclear refueling outage costs 46,544 58,119 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Prepayments and other 122,690 78,567 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------- ----------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 3,958,015 3,203,985 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------- ----------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql OTHER PROPERTY AND INVESTMENTS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Investment in subsidiary companies - at equity 214 214 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Decommissioning trust funds 1,315,857 1,246,023 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Non-utility property - at cost (less accumulated depreciation) 334,270 317,165 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Non-regulated investments 331,604 198,003 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other - at cost (less accumulated depreciation) 22,298 16,714 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------- ----------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 2,004,243 1,778,119 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------- ----------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql UTILITY PLANT \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Electric 25,137,562 23,163,161 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Plant acquisition adjustment 390,664 406,929 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Property under capital lease 769,370 768,500 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Natural gas 190,989 186,041 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Construction work in progress 936,785 1,500,617 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Nuclear fuel under capital lease 277,673 286,476 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Nuclear fuel 157,603 87,693 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------- ----------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL UTILITY PLANT 27,860,646 26,399,417 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Less - accumulated depreciation and amortization 11,364,021 10,898,661 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------- ----------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql UTILITY PLANT - NET 16,496,625 15,500,756 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------- ----------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql DEFERRED DEBITS AND OTHER ASSETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Regulatory assets: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Rate deferrals - 16,581 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql SFAS 109 regulatory asset - net 980,266 1,068,006 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Unamortized loss on reacquired debt 183,627 198,631 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Deferred fuel costs 95,661 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other regulatory assets 792,515 637,870 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Long-term receivables 29,575 32,260 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 1,024,700 533,732 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------- ----------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 3,106,344 2,487,080 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------- ----------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL ASSETS $25,565,227 $22,969,940 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql =========== =========== \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql CONSOLIDATED BALANCE SHEETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql LIABILITIES AND SHAREHOLDERS' EQUITY \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql CURRENT LIABILITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Currently maturing long-term debt $464,215 $194,555 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Notes payable 388,023 120,715 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Accounts payable 1,204,227 707,678 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Customer deposits 172,169 161,909 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Taxes accrued 451,811 445,677 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Accumulated deferred income taxes 225,649 72,640 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Nuclear refueling outage costs 10,209 11,216 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Interest accrued 172,033 129,028 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Obligations under capital leases 156,907 178,247 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Other 192,908 125,749 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ----------- ----------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql TOTAL 3,438,151 2,147,414 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ----------- ----------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql DEFERRED CREDITS AND OTHER LIABILITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Accumulated deferred income taxes 3,249,083 3,310,340 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Accumulated deferred investment tax credits 494,315 519,910 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Obligations under capital leases 201,873 205,464 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql FERC settlement - refund obligation 30,745 37,337 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Other regulatory liabilities 218,172 199,139 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Decommissioning 749,708 703,453 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Transition to competition 191,934 157,034 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Regulatory reserves 396,789 378,307 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Accumulated provisions 390,116 279,425 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Other 853,137 527,027 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ----------- ----------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql TOTAL 6,775,872 6,317,436 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ----------- ----------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Long-term debt 7,732,093 6,612,583 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Preferred stock with sinking fund 65,758 69,650 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Preference stock - 150,000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Company-obligated mandatorily redeemable \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql preferred securities of subsidiary trust holding \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql solely junior subordinated deferrable debentures 215,000 215,000 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql SHAREHOLDERS' EQUITY \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Preferred stock without sinking fund 334,688 338,455 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Common stock, $.01 par value, authorized 500,000,000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql shares; issued 248,094,614 shares in 2000 and \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql 247,082,345 shares in 1999 2,481 2,471 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Paid-in capital 4,660,483 4,636,163 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Retained earnings 3,190,639 2,786,467 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Accumulated other comprehensive income: \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Cumulative foreign currency translation adjustment (73,998) (68,782) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Net unrealized investment losses (1,035) (5,023) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Less - treasury stock, at cost (28,490,031 shares in 2000 and \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql 8,045,434 shares in 1999) 774,905 231,894 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ----------- ----------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql TOTAL 7,338,353 7,457,857 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ----------- ----------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Commitments and Contingencies (Notes 2, 9, 10, and 11) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $25,565,227 $22,969,940 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql =========== =========== \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql CONSOLIDATED STATEMENTS OF RETAINED EARNINGS, COMPREHENSIVE INCOME, AND PAID-IN CAPITAL \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql RETAINED EARNINGS \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Retained Earnings - Beginning of period $2,786,467 $2,526,888 $2,157,912 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Add - Earnings applicable to common stock 679,294 $679,294 552,459 $552,459 739,069 $739,069 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Deduct: \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Dividends declared on common stock 275,929 294,352 369,498 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Capital stock and other expenses (807) (1,472) 595 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ---------- ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Total 275,122 292,880 370,093 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ---------- ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Retained Earnings - End of period $3,190,639 $2,786,467 $2,526,888 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ========== ========== ========== \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS): \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Balance at beginning of period ($73,805) ($46,739) ($69,817) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Foreign currency translation adjustments (5,216) (5,216) (22,043) (22,043) 23,078 23,078 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Net unrealized investment gains (losses) 3,988 3,988 (5,023) (5,023) - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Balance at end of period ($75,033) ($73,805) ($46,739) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ======== -------- ======== -------- ======== -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Comprehensive Income $678,066 $525,393 $762,147 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ======== ======== ======== \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql PAID-IN CAPITAL \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Paid-in Capital - Beginning of period $4,636,163 $4,630,609 $4,613,572 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Add: \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Common stock issuances related to stock plans 24,320 5,554 17,037 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Paid-in Capital - End of period $4,660,483 $4,636,163 $4,630,609 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ========== ========== ========== \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 (1) 1997 (2) 1996 (3) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands, Except Percentages and Per Share Amounts) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operating revenues $10,016,148 $ 8,773,228 $11,494,772 $ 9,538,926 $ 7,163,526 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Consolidated net income $ 710,915 $ 595,026 $ 785,629 $ 300,899 $ 490,563 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Earnings per share \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Basic $ 3.00 $ 2.25 $ 3.00 $ 1.03 $ 1.83 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Diluted $ 2.97 $ 2.25 $ 3.00 $ 1.03 $ 1.83 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Dividends declared per share $ 1.22 $ 1.20 $ 1.50 $ 1.80 $ 1.80 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Return on average common equity 9.62% 7.77% 10.71% 3.71% 6.41% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Book value per share, year-end $ 31.89 $ 29.78 $ 28.82 $ 27.23 $ 28.51 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total assets $25,565,227 $22,969,940 $22,836,694 $27,000,700 $22,956,025 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term obligations (4) $ 8,214,724 $ 7,252,697 $ 7,349,349 $10,154,330 $ 8,335,150 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (1) Includes the effects of the sales of London Electricity and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql CitiPower in December 1998. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (2) Includes the effects of the London Electricity acquisition in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql February 1997. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (3) Includes the effects of the CitiPower acquisition in January 1996. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (4) Includes long-term debt (excluding currently maturing debt), \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql preferred stock with sinking fund, preference stock, preferred \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql securities of subsidiary trusts and partnership, and noncurrent \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql capital lease obligations. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 1998 1997 1996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (Dollars In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Domestic Electric Operating Revenues: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Residential $2,524,529 $2,231,091 $2,299,317 $2,271,363 $2,277,647 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Commercial 1,699,699 1,502,267 1,513,050 1,581,878 1,573,251 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Industrial 2,177,236 1,878,363 1,829,085 2,018,625 1,987,640 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Governmental 185,286 163,403 172,368 171,773 169,287 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql --------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total retail 6,586,750 5,775,124 5,813,820 6,043,639 6,007,825 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Sales for resale 423,519 397,844 448,842 359,881 376,011 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other (1) 209,417 98,446 (126,340) 135,311 67,104 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql --------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total $7,219,686 $6,271,414 $6,136,322 $6,538,831 $6,450,940 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql =============================================================== \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Billed Electric Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Sales (GWH): \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Residential 31,998 30,631 30,935 28,286 28,303 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Commercial 24,657 23,775 23,177 21,671 21,234 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Industrial 43,956 43,549 43,453 44,649 44,340 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Governmental 2,605 2,564 2,659 2,507 2,449 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql --------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total retail 103,216 100,519 100,224 97,113 96,326 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Sales for resale 9,794 9,714 11,187 9,707 10,583 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql --------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total 113,010 110,233 111,411 106,820 106,909 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql =============================================================== \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (1) 1998 includes the effect of a reserve for rate refund at Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Gulf States. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\f0\fs16\par\pard\plain\cf1\f50\fs16\ql Report of Independent Accountants \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql To the Board of Directors and Shareholders of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Inc.: \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In our opinion, the accompanying balance sheets and the related statements \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of income, of retained earnings and of cash flows (pages 86 through 91 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and pages 147 through 209) present fairly, in all material respects, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial position of Entergy Arkansas, Inc. at December 31, 2000 and 1999, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and the results of its operations and its cash flows for each of the three \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql years in the period ended December 31, 2000 in conformity with accounting \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql principles generally accepted in the United States of America. These \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial statements are the responsibility of the Company's management; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql our responsibility is to express an opinion on these financial statements \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql based on our audits. We conducted our audits of these statements in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accordance with auditing standards generally accepted in the United States \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of America, which require that we plan and perform the audit to obtain \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reasonable assurance about whether the financial statements are free of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql material misstatement. An audit includes examining, on a test basis, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql evidence supporting the amounts and disclosures in the financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements, assessing the accounting principles used and significant \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql estimates made by management, and evaluating the overall financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statement presentation. We believe that our audits provide a reasonable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql basis for our opinion. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PricewaterhouseCoopers LLP \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans, Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql February 1, 2001 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY ARKANSAS, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net Income \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income increased in 2000 primarily due to increased electric \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operating revenues and lower regulatory charges, partially offset by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increased operation and maintenance expenses. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income decreased in 1999 primarily due to decreased electric \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operating revenues and increased operation and maintenance expenses, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql partially offset by lower regulatory charges. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Revenues and Sales \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The changes in electric operating revenues for the twelve months ended \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, 2000 and 1999 are as follows: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Increase/(Decrease) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Description 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Millions) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Base revenues ($6.5) $4.5 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Rate riders (21.8) (68.2) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel cost recovery 61.8 36.4 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales volume/weather 30.8 3.8 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other revenue (including unbilled) 47.6 (25.2) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales for resale 108.8 (18.1) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------ ------ \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total $220.7 ($66.8) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ====== ====== \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Rate riders \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Rate rider revenues have no material effect on net income because \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql specific incurred expenses offset them. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, rate rider revenues decreased as a result of the decreased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ANO Decommissioning and Grand Gulf rate riders, both of which became \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql effective in January 2000. The ANO Decommissioning rider allows Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas to recover the decommissioning costs associated with ANO 1 and 2. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The Grand Gulf rate rider allows Entergy Arkansas to recover its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recoverable share of operating costs for Grand Gulf 1. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, rate rider revenues decreased as a result of a revised Grand \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf rider, which includes the completion of the Grand Gulf 1 phase-in plan \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in November 1998, partially offset by the Grand Gulf Accelerated Recovery \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Tariff (GGART). The GGART is designed to allow Entergy Arkansas to pay \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql down a portion of its Grand Gulf purchased power obligation in advance of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the implementation of retail access in Arkansas. The rider and GGART \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql became effective with the first billing cycle in January 1999. The GGART \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql is discussed further in Note 2 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel cost recovery \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas is allowed to recover certain fuel and purchased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power costs through fuel mechanisms included in electric rates that are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recorded as fuel cost recovery revenues. The difference between revenues \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql collected and current fuel and purchased power costs is recorded as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deferred fuel costs on Entergy Arkansas' financial statements such that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql these costs generally have no net effect on earnings. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY ARKANSAS, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel cost recovery revenues increased in 2000 primarily due to an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increase in the energy cost rate in April 2000, which is determined \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql annually by a formula in the energy cost recovery rider (Rider ECR) in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql April 2000. The increase in the energy cost rate allows Entergy Arkansas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to recover previously deferred fuel expenses. Rider ECR is discussed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql further in Note 2 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel cost recovery revenues increased in 1999 due to an increase in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the energy cost recovery rider, effective in April 1999, and the completion \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of a customer refund obligation in 1998, which lowered 1998 fuel cost \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovery. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales volume/weather \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales volume increased in 2000 primarily due to increased usage by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql industrial, commercial, and residential customers, as well as the effect of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql more favorable weather on the residential and commercial sectors. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other revenue (including unbilled) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, other revenue increased primarily as a result of a change in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql estimated unbilled revenues and a $13.4 million adjustment to third quarter \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999 unbilled revenues that excluded fuel recovery and rate rider revenues \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql from the unbilled balance in accordance with regulatory treatment. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql change in estimate is discussed below. Unbilled revenues also increased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to greater unbilled volume and the addition of unbilled revenue for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql wholesale customers to the unbilled balance. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, other revenue decreased primarily as a result of a change in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql estimated unbilled revenues in the second quarter and, to a lesser extent, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql less favorable weather for the unbilled period of 1999. The changed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql estimate more closely aligns the fuel component of unbilled revenue with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql its regulatory treatment. Comparative impacts are also affected by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql seasonal impacts on demand. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales for resale \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, sales for resale increased primarily due to an increase in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the market price of electricity. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, sales for resale decreased due to the loss of certain \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql municipal and co-op customer contracts. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel and purchased power expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, fuel and purchased power expenses increased primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in the market price of natural gas; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in the market price of purchased power; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased purchased power volume due to increased demand for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql electricity and to offset decreased nuclear generation due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql maintenance, inspection, and refueling outages during the year. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The increased fuel and purchased power expenses were partially offset by a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $23.5 million adjustment to the deferred fuel balance as a result of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999 and 2000 ECR filings. This adjustment reflects deferred costs that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas expects to recover in the future. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY ARKANSAS, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, fuel and purchased power expenses increased primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o higher-priced gas generation as a result of refueling outages at ANO 1 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and ANO 2, a mid-cycle maintenance outage at ANO 2, limited coal \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql capability at White Bluff during parts of the year, and displacement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of higher priced purchased power; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased purchased power costs due to higher market prices in July \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and August 1999; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in the energy cost recovery rate in April 1999 and the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql completion of a customer refund obligation in 1998 which lowered 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel cost recovery. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The increase in the energy cost recovery rate allows Entergy Arkansas to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recover previously under-recovered fuel expenses. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other operation and maintenance \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other operation and maintenance expenses increased for 2000 primarily \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in property damage expense of $14.5 million due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 2000 ice storms; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in nuclear expenses of $7.9 million related to maintenance \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and inspection outages and the steam generator replacement project at \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ANO 2; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in spending of $7.1 million on vegetation management; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in plant maintenance expense of $5.0 million; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in spending of $4.5 million for outside services employed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql related primarily to legal and contract services for transition work. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other operation and maintenance expenses increased for 1999 primarily \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in customer service costs of $12.9 million related to tree \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql trimming around power lines; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in plant maintenance costs of $7.9 million; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in employee pension and benefits costs of $5.0 million; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in administrative and general salaries expense of $4.5 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Decommissioning \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Decommissioning expense decreased primarily due to a true-up of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decommissioning liability in June 2000 for previous over-accruals. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory charges (credits) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, other regulatory credits increased primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a $16.6 million under-recovery of Grand Gulf 1 costs as a result of a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decreased rate rider that became effective in January 2000 as ordered \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by the APSC; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the recording of a regulatory asset for certain transition costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expected to be recovered in a customer transition tariff; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o accruals in 1999 of excess earnings in the transition cost account. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accruals previously made in 2000 for estimated excess earnings were \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reversed in order to offset expenses related to the December ice storms. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY ARKANSAS, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, other regulatory charges decreased primarily as a result of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql lower accruals for transition costs in 1999, partially offset by the 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reversal of the 1997 reserve recorded for the low-level radioactive waste \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql facility. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The transition cost account and the December 2000 ice storms are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql discussed in more detail in Note 2 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Amortization of rate deferrals \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, amortization of rate deferrals decreased due to the November \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1998 completion of the Grand Gulf 1 rate phase-in plan. These phase-ins \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql had no material effect on net income. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest charges \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest charges increased in 2000 due to the issuance of $100 million \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of long-term debt in March 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest charges decreased in 1999 due to the retirement of certain \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql long-term debt and decreased borrowings for funds used during construction. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql These decreases were partially offset by an adjustment for interest expense \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql on an income tax settlement from prior years. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The effective income tax rates for 2000, 1999, and 1998 were 42.3%, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 43.8%, and 39.1%, respectively. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The effective income tax rate increased in 1999 primarily due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accelerated tax depreciation deductions for which deferred taxes have not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql been previously normalized, reflecting a shorter tax life on certain \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql assets. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY ARKANSAS, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INCOME STATEMENTS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING REVENUES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Domestic electric $1,762,635 $1,541,894 $1,608,698 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING EXPENSES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operating and Maintenance: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel, fuel-related expenses, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql gas purchased for resale 258,294 257,946 204,318 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Purchased power 560,793 455,425 419,947 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nuclear refueling outage expenses 25,884 29,857 32,046 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other operation and maintenance 427,409 389,462 358,006 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Decommissioning 3,845 10,670 15,583 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Taxes other than income taxes 39,662 36,669 37,223 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation and amortization 169,806 161,234 165,853 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory charges (credits) - net (33,078) 5,230 45,658 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Amortization of rate deferrals - - 75,249 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 1,452,615 1,346,493 1,353,883 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING INCOME 310,020 195,401 254,815 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OTHER INCOME \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for equity funds used during construction 15,020 12,866 5,921 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gain (loss) on sale of assets (8) - 1,777 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Miscellaneous - net 4,339 3,622 12,292 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 19,351 16,488 19,990 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INTEREST AND OTHER CHARGES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest on long-term debt 88,140 80,800 86,772 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other interest - net 8,360 11,123 4,813 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Distributions on preferred securities of subsidiary 5,100 5,100 5,100 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for borrowed funds used during construction (9,788) (8,459) (4,205) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 91,812 88,564 92,480 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INCOME BEFORE INCOME TAXES 237,559 123,325 182,325 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes 100,512 54,012 71,374 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql NET INCOME 137,047 69,313 110,951 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred dividend requirements and other 7,776 10,854 10,201 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql EARNINGS APPLICABLE TO \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql COMMON STOCK $129,271 $58,459 $100,750 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ========== ========== ========== \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY ARKANSAS, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql STATEMENTS OF CASH FLOWS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income $137,047 $69,313 $110,951 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Noncash items included in net income: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Amortization of rate deferrals - - 75,249 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory charges (credits) - net (33,078) 5,230 45,658 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation, amortization, and decommissioning 173,651 171,904 181,436 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deferred income taxes and investment tax credits 39,776 22,421 (12,293) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for equity funds used during construction (15,020) (12,866) (5,921) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (Gain) loss on sale of assets 8 - (1,777) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Changes in working capital: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Receivables (47,647) 40,375 61,143 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel inventory (6,512) (4,633) 8,317 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accounts payable 141,172 56,985 (7,911) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Taxes accrued 1,731 (30,054) (8,742) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest accrued 5,246 (2,908) (3,541) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deferred fuel costs 35,993 38,814 (17,575) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other working capital accounts 17,162 2,444 (6,845) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Provision for estimated losses and reserves (895) (8,116) 2,032 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Changes in other regulatory assets (85,452) 45,898 (13,029) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 58,378 (42,249) 41,499 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql --------- --------- --------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow provided by operating activities 421,560 352,558 448,651 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql --------- --------- --------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INVESTING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Construction expenditures (369,370) (238,009) (190,459) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for equity funds used during construction 15,020 12,866 5,921 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nuclear fuel purchases (44,722) (32,517) (45,845) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Proceeds from sale/leaseback of nuclear fuel 44,722 32,517 42,055 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Decommissioning trust contributions and realized \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql change in trust assets (15,761) (17,746) (25,929) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory investments (97,343) (39,243) (39,860) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql --------- --------- --------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow used in investing activities (467,454) (282,132) (254,117) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql --------- --------- --------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FINANCING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Proceeds from issuance of: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term debt 99,381 - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retirement of: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term debt (220) (39,607) (151,424) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Redemption of preferred stock - (22,666) (9,000) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Dividends paid: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Common stock (44,600) (82,700) (92,600) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred stock (7,691) (11,696) (10,407) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql --------- --------- --------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow provided by (used in) financing activities 46,870 (156,669) (263,431) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql --------- --------- --------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net increase (decrease) in cash and cash equivalents 976 (86,243) (68,897) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and cash equivalents at beginning of period 6,862 93,105 162,002 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql --------- --------- --------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and cash equivalents at end of period $7,838 $6,862 $93,105 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ========= ========= ========= \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash paid during the period for: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest - net of amount capitalized $91,291 $94,872 $95,050 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes $60,291 $61,273 $91,407 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Noncash investing and financing activities: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Change in unrealized appreciation/(depreciation) of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decommissioning trust assets ($3,920) $22,980 $26,782 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ENTERGY ARKANSAS, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql BALANCE SHEETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ASSETS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql CURRENT ASSETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Cash and cash equivalents $7,838 $6,862 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accounts receivable: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Customer 98,550 73,357 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Allowance for doubtful accounts (1,667) (1,768) \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Associated companies 22,286 26,816 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 26,221 11,625 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accrued unbilled revenues 65,887 53,600 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total receivables 211,277 163,630 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Deferred fuel costs 102,970 41,620 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Fuel inventory - at average cost 9,809 3,297 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Materials and supplies - at average cost 80,682 85,612 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Deferred nuclear refueling outage costs 23,541 28,119 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Prepayments and other 5,540 6,480 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 441,657 335,620 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql OTHER PROPERTY AND INVESTMENTS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Investment in subsidiary companies - at equity 11,217 11,215 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Decommissioning trust funds 355,852 344,011 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Non-utility property - at cost (less accumulated depreciation) 1,469 1,463 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other - at cost (less accumulated depreciation) 3,032 3,033 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 371,570 359,722 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql UTILITY PLANT \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Electric 5,274,066 4,854,433 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Property under capital lease 40,289 44,471 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Construction work in progress 87,389 267,091 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Nuclear fuel under capital lease 107,023 85,725 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Nuclear fuel 6,720 9,449 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL UTILITY PLANT 5,515,487 5,261,169 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Less - accumulated depreciation and amortization 2,449,821 2,401,021 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql UTILITY PLANT - NET 3,065,666 2,860,148 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql DEFERRED DEBITS AND OTHER ASSETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Regulatory assets: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql SFAS 109 regulatory asset - net 162,952 192,344 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Unamortized loss on reacquired debt 44,428 48,193 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other regulatory assets 221,805 106,959 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 4,775 14,125 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 433,960 361,621 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL ASSETS $4,312,853 $3,917,111 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ========== ========== \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ENTERGY ARKANSAS, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql BALANCE SHEETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql LIABILITIES AND SHAREHOLDERS' EQUITY \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql CURRENT LIABILITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Currently maturing long-term debt $100 $220 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Notes payable 667 667 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accounts payable: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Associated companies 94,776 81,958 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 231,313 102,959 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Customer deposits 29,775 26,320 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Taxes accrued 40,263 38,532 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accumulated deferred income taxes 55,127 38,649 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Interest accrued 27,624 22,378 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Obligations under capital leases 45,962 55,150 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 14,942 11,598 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 540,549 378,431 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql DEFERRED CREDITS AND OTHER LIABILITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accumulated deferred income taxes 715,891 713,622 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accumulated deferred investment tax credits 88,264 94,852 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Obligations under capital leases 101,350 75,045 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other regulatory liabilities 84,642 88,563 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Transition to competition 119,553 109,933 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accumulated provisions 42,393 43,288 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 64,267 51,015 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 1,216,360 1,176,318 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Long-term debt 1,239,712 1,130,801 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Company-obligated mandatorily redeemable \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql preferred securities of subsidiary trust holding \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql solely junior subordinated deferrable debentures 60,000 60,000 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql SHAREHOLDERS' EQUITY \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Preferred stock without sinking fund 116,350 116,350 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Common stock, $0.01 par value, authorized 325,000,000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql shares; issued and outstanding 46,980,196 shares in 2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql and 1999 470 470 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Paid-in capital 591,127 591,127 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Retained earnings 548,285 463,614 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 1,256,232 1,171,561 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Commitments and Contingencies (Notes 2, 9, and 10) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $4,312,853 $3,917,111 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ========== ========== \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql See Notes to Financial Statements. \par\pard\plain\fs16 \page\par\pard\plain\f0\fs16\par\pard\plain\cf1\f50\fs16\ql ENTERGY ARKANSAS, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql STATEMENTS OF RETAINED EARNINGS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retained Earnings, January 1 $463,614 $487,855 $479,705 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Add: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income 137,047 69,313 110,951 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deduct: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Dividends declared: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred stock 7,776 9,223 10,201 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Common stock 44,600 82,700 92,600 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Capital stock expenses and other - 1,631 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total 52,376 93,554 102,801 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retained Earnings, December 31 (Note 8) $548,285 $463,614 $487,855 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ======== ======== ======== \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ENTERGY ARKANSAS, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 1998 1997 1996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Operating revenues $1,762,635 $1,541,894 $1,608,698 $1,715,714 $1,743,433 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Net income $ 137,047 $ 69,313 $ 110,951 $ 127,977 $ 157,798 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total assets $4,312,853 $3,917,111 $4,006,651 $4,106,877 $4,153,817 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Long-term obligations (1) $1,401,062 $1,265,846 $1,335,248 $1,419,728 $1,439,355 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (1) Includes long-term debt (excluding currently maturing debt), \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql preferred securities of subsidiary trust, and noncurrent capital \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql lease obligations. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 1998 1997 1996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (Dollars In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Electric Operating Revenues: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Residential $561,363 $533,245 $562,325 $551,821 $546,100 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Commercial 307,320 288,677 288,816 332,715 323,328 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Industrial 353,046 335,824 330,016 372,083 364,943 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Governmental 14,935 14,606 14,640 18,200 16,989 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total retail 1,236,664 1,172,352 1,195,797 1,274,819 1,251,360 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Sales for resale: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Associated companies 245,541 178,150 149,603 213,845 248,211 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Non-associated companies 234,873 193,449 240,090 215,249 207,887 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 45,557 (2,057) 23,208 11,801 35,975 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total $1,762,635 $1,541,894 $1,608,698 $1,715,714 $1,743,433 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql =========================================================== \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Billed Electric Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Sales (GWH): \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Residential 6,791 6,493 6,613 5,988 6,023 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Commercial 5,063 4,880 4,773 4,445 4,390 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Industrial 7,240 7,054 6,837 6,647 6,487 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Governmental 239 237 233 239 234 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total retail 19,333 18,664 18,456 17,319 17,134 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Sales for resale: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Associated companies 6,513 7,592 6,500 9,557 10,471 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Non-associated companies 5,537 4,868 5,948 6,828 6,720 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total 31,383 31,124 30,904 33,704 34,325 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql =========================================================== \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\f0\fs16\par\pard\plain\cf1\f50\fs16\ql Report of Independent Accountants \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql To the Board of Directors and Shareholders of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States, Inc.: \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In our opinion, the accompanying balance sheets and the related statements \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of income, of retained earnings and of cash flows (pages 99 through 103 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and pages 147 through 209) present fairly, in all material respects, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial position of Entergy Gulf States, Inc. at December 31, 2000 and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999, and the results of its operations and its cash flows for each of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql three years in the period ended December 31, 2000 in conformity with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accounting principles generally accepted in the United States of America. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql These financial statements are the responsibility of the Company's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql management; our responsibility is to express an opinion on these financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements based on our audits. We conducted our audits of these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements in accordance with auditing standards generally accepted in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql United States of America, which require that we plan and perform the audit \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to obtain reasonable assurance about whether the financial statements are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql free of material misstatement. An audit includes examining, on a test \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql basis, evidence supporting the amounts and disclosures in the financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements, assessing the accounting principles used and significant \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql estimates made by management, and evaluating the overall financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statement presentation. We believe that our audits provide a reasonable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql basis for our opinion. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PricewaterhouseCoopers LLP \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans, Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql February 1, 2001 \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY GULF STATES, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net Income \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income increased in 2000 primarily due to increased sales volume, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increased unbilled revenue, increased wholesale revenue, and decreased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulatory reserves. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income increased in 1999 primarily due to increased unbilled \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql revenues, decreased provisions for rate refunds in 1999, decreased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql depreciation and amortization expenses, and decreased interest expense, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql partially offset by increased operation and maintenance expenses. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Revenues and Sales \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Electric operating revenues \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The changes in electric operating revenues for the twelve months ended \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, 2000 and 1999 are as follows: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Increase/(Decrease) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Description 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Millions) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Base revenues ($83.2) $146.4 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel cost recovery 342.5 104.9 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales volume/weather 40.7 1.0 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other revenue (including unbilled) 29.8 31.3 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales for resale 58.7 21.2 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------ ------ \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total $388.5 $304.8 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ====== ====== \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Base revenues \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, base revenues decreased primarily due to the reversal in 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of regulatory reserves discussed below associated with the accelerated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amortization of accounting order deferrals and rate refunds in conjunction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with the Texas rate settlement. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, base revenues increased due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a $93.6 million reversal in June 1999 of regulatory reserves \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql associated with the accelerated amortization of accounting order \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deferrals in conjunction with the settlement agreement in Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States' Texas November 1996 and 1998 rate filings. The settlement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql agreement was approved by the PUCT in June 1999. The net income effect \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of this reversal is largely offset by the amortization of rate deferrals \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql discussed below; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a reduction in the amount of reserves recorded in 1999 compared to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1998 for the anticipated effects of rate proceedings in Texas. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Partially offsetting these increases in 1999 were: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o annual base rate reductions of $87 million and $18 million that were \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql implemented for Louisiana retail customers in February and August 1998, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql respectively; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o annual base rate reductions of $69 million and $4.2 million that were \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql implemented for Texas retail customers in December 1998 and March 1999, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql respectively; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o reserves recorded in the Louisiana jurisdiction in 1999 for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql estimated outcomes of earnings reviews. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY GULF STATES, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The LPSC and PUCT rate issues are discussed in Note 2 to the financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel cost recovery \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States is allowed to recover certain fuel and purchased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power costs through fuel mechanisms included in electric rates that are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recorded as fuel cost recovery revenues. The difference between revenues \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql collected and current fuel and purchased power costs is recorded as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deferred fuel costs on Entergy Gulf States' financial statements such that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql these costs generally have no net effect on earnings. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, fuel cost recovery revenues increased primarily due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increased market prices for fuel and purchased power, resulting in an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increased recovery of $226.7 million in the Louisiana jurisdiction. Fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cost recovery revenues increased in the Texas jurisdiction by $82.4 million \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to a higher fuel recovery factor that became effective in September \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999 and by $33.4 million due to a fuel surcharge implemented in January \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, fuel cost recovery revenues increased due to a higher fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql factor in 1999 and a fuel surcharge implemented in February 1999 in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Texas jurisdiction. This increase was partially offset by reduced fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovery in the Louisiana jurisdiction primarily due to lower fuel and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchased power costs in 1999. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales volume/weather \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, sales volume increased due to more favorable weather \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql affecting residential and commercial customers, as well as an increase in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the number of residential and commercial customers. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other revenue \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, other revenue increased primarily due to increased unbilled \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql revenues due to the effect of a change in estimate on unbilled revenue, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql more favorable weather, and increased sales volume. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, other revenue increased primarily due to a change in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql estimated unbilled revenues. The estimate more closely aligns the fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql component of unbilled revenues with regulatory treatment. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales for resale \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, sales for resale increased primarily due to increased sales \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql volume including sales of energy from the non-regulated piece of River Bend \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to affiliated companies. Sales for resale also increased due to increased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generation, particularly nuclear generation, resulting in more energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql available for resale. Nuclear generation was down in 1999 as a result of a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql nuclear refueling outage. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, sales for resale increased primarily due to increased sales \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to associated companies due to higher market prices and outages at \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql affiliate plants in 1999. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gas and steam operating revenues \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gas operating revenues increased in 2000 due to an increase in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql market price for natural gas as well as increased sales volume in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql residential and commercial sectors. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY GULF STATES, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, gas operating revenues decreased primarily due to lower \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql prices of gas purchased for resale as well as decreased usage as a result \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of warmer winter weather, particularly in the residential and commercial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql sectors. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000 and in 1999, steam operating revenues decreased primarily due \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to a new lease arrangement that began in June 1999 for the Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Station generating facility. Under the terms of this new lease, revenues \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and expenses are now classified as other income. The previous \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql classifications were steam operating revenues and other operation and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql maintenance expenses. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel and purchased power \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, fuel and purchased power expenses increased primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o higher market prices for gas and purchased power; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased nuclear generation; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an adjustment in March 2000 of $11.5 million to the Texas jurisdiction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deferred fuel balance as a result of a fuel reconciliation settlement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with the PUCT. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, fuel and purchased power expenses increased due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased gas expenses resulting from a shift to gas generation during \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the first six months of 1999 because of the reduced availability of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nelson 6 and an extended refueling outage at River Bend; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased purchased power expenses due to higher market prices; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a higher fuel factor and fuel surcharge in the Texas jurisdiction in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other operation and maintenance expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, other operation and maintenance expenses increased primarily \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to increased expenses of $12.6 million on outside services employed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql related to legal and contract services for transition work and increased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql nuclear plant operations costs of $5.8 million. These increases were \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql largely offset by decreases in pension and benefits costs of $7.3 million \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and decreased environmental reserves of $5.7 million. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, other operation and maintenance expenses increased primarily \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to increased spending of $8.4 million for vegetation management, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increased miscellaneous customer expenses of $2.5 million, and due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increased property and environmental reserves of $4.9 million. These \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increases were offset primarily by decreases of $8.8 million for pension \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and benefits expenses. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation and amortization \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, depreciation and amortization increased primarily due to a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql review of plant-in-service dates for consistency with regulatory treatment \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reducing depreciation expense by $6.7 million in 1999, as well as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql additional depreciation expense related to net capital additions in 2000. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY GULF STATES, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, depreciation and amortization decreased due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o lower depreciation as a result of the write-down of the River Bend \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql abeyed plant as required by the Texas rate settlement; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o reduced amortization of the River Bend Unit 2 cancellation loss as a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql result of the completion of amortization for the Louisiana portion of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the loss and the reduction in amortization of the Texas portion in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accordance with a PUCT rate order; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o lower depreciation due to a review of plant in-service dates for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql consistency with regulatory treatment. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory credits \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, other regulatory credits decreased due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the amortization of the Year 2000 regulatory asset deferred in 1999; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the completion of the amortization of the deferred financing costs in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accordance with the December 1998 rate order settlement with the PUCT. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, other regulatory credits increased due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o change in the amortization period for deferred River Bend finance \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql charges for the Texas retail jurisdiction in accordance with the Texas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql settlement agreement; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o deferral of Year 2000 costs in accordance with an LPSC order. These \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs are to be amortized over a five-year period. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Amortization of rate deferrals \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, the amortization of rate deferrals decreased primarily due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the large reduction in the rate deferral balance upon the PUCT's approval \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in June 1999 of the Texas rate settlement. This settlement increased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amortization expense in 1999 but was offset by increased revenues. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, the amortization of rate deferrals increased due to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reduction of accounting order deferrals in accordance with the June 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Texas settlement agreement. This settlement substantially reduced the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql unamortized balance of rate deferrals, while decreasing the amortization \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql period for the remaining deferrals from a ten-year period to a three-year \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql period. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other income \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, other income decreased primarily due to decreased non-utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operating income from Louisiana Station as well as the 1999 adjustment to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the depreciation balance of River Bend abeyed plant. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY GULF STATES, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest charges \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, interest charges increased as a result of the issuance of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $300 million of long term debt in 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, interest charges decreased as a result of the retirement, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql redemption, and refinancing of certain long-term debt in 1998 and 1999, as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql well as lower accruals of interest on certain Louisiana fuel and earnings \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reviews in 1998. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The effective income tax rates for 2000, 1999, and 1998 are 36.5%, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 37.6%, and 40.6%, respectively. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The decrease in the effective income tax rate in 1999 is due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accelerated tax depreciation deductions for which deferred taxes have not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql been previously normalized, reflecting a shorter tax life on certain \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql assets. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ENTERGY GULF STATES, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql INCOME STATEMENTS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql OPERATING REVENUES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Domestic electric $2,470,884 $2,082,358 $1,777,584 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Natural gas 40,356 28,998 33,058 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Steam products - 15,852 43,167 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 2,511,240 2,127,208 1,853,809 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql OPERATING EXPENSES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Operating and Maintenance: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Fuel, fuel-related expenses, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql gas purchased for resale 895,361 634,726 538,388 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Purchased power 455,300 365,245 317,684 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Nuclear refueling outage expenses 16,663 16,307 14,293 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other operation and maintenance 423,031 419,713 411,372 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Decommissioning 6,273 7,588 3,437 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Taxes other than income taxes 120,428 111,872 120,782 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Depreciation and amortization 189,149 185,254 195,935 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other regulatory credits - net (13,860) (24,092) (5,485) \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Amortization of rate deferrals 5,606 89,597 21,749 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 2,097,951 1,806,210 1,618,155 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql OPERATING INCOME 413,289 320,998 235,654 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql OTHER INCOME \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Allowance for equity funds used during construction 7,617 6,306 2,143 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Gain on sale of assets 2,327 2,046 1,816 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Miscellaneous - net 12,736 18,073 14,903 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 22,680 26,425 18,862 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql INTEREST AND OTHER CHARGES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Interest on long-term debt 143,053 138,602 149,767 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other interest - net 8,458 6,994 21,016 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Distributions on preferred securities of subsidiary 7,438 7,438 7,437 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Allowance for borrowed funds used during construction (6,926) (5,776) (1,870) \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 152,023 147,258 176,350 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql INCOME BEFORE INCOME TAXES 283,946 200,165 78,166 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Income taxes 103,603 75,165 31,773 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql NET INCOME 180,343 125,000 46,393 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Preferred dividend requirements and other 9,998 17,423 19,011 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql EARNINGS APPLICABLE TO \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql COMMON STOCK $170,345 $107,577 $27,382 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ========== ========== ========== \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY GULF STATES, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql STATEMENTS OF CASH FLOWS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income $180,343 $125,000 $46,393 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Noncash items included in net income: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Amortization of rate deferrals 5,606 89,597 21,749 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Reserve for regulatory adjustments (49,571) (97,953) 130,603 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory credits - net (13,860) (24,092) (5,485) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation, amortization, and decommissioning 195,422 192,842 199,372 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deferred income taxes and investment tax credits 54,279 (1,495) (29,174) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for equity funds used during construction (7,617) (6,306) (2,143) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gain on sale of assets (2,327) (2,046) (1,816) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Changes in working capital: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Receivables (131,643) 9,791 65,527 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel inventory 1,013 (8,070) 7,426 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accounts payable 130,435 42,370 (6,135) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Taxes accrued 30,570 46,018 7,462 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest accrued 14,969 (14,061) (2,523) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deferred fuel costs (26,291) 40,851 55,985 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other working capital accounts 20,896 (10,954) 11,006 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Provision for estimated losses and reserves (1,991) 8,496 (4,207) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Changes in other regulatory assets (47,777) (59,242) (3,226) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 51,424 56,817 458 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow provided by operating activities 403,880 387,563 491,272 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INVESTING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Construction expenditures (277,635) (199,076) (136,960) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for equity funds used during construction 7,617 6,306 2,143 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nuclear fuel purchases (34,735) (53,293) (1,977) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Proceeds from sale/leaseback of nuclear fuel 34,154 53,293 15,932 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Decommissioning trust contributions and realized \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql change in trust assets (12,051) (10,853) (11,899) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory investments (127,377) (42,412) (43,124) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow used in investing activities (410,027) (246,035) (175,885) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FINANCING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Proceeds from issuance of: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term debt 298,819 122,906 21,600 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retirement of: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term debt (185) (197,960) (212,090) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Redemption of preferred stock (157,658) (25,931) (8,481) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Dividends paid: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Common stock (88,000) (107,000) (109,400) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred stock (10,862) (16,967) (19,055) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow provided by (used in) financing activities 42,114 (224,952) (327,426) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net increase (decrease) in cash and cash equivalents 35,967 (83,424) (12,039) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and cash equivalents at beginning of period 32,312 115,736 127,775 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and cash equivalents at end of period $68,279 $32,312 $115,736 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ======== ======== ======== \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash paid during the period for: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest - net of amount capitalized $136,154 $161,326 $173,599 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes $23,259 $28,410 $46,620 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Noncash investing and financing activities: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Change in unrealized appreciation/(depreciation) of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decommissioning trust assets ($3,172) $14,054 $10,410 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ENTERGY GULF STATES, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql BALANCE SHEETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ASSETS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql CURRENT ASSETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Cash and cash equivalents: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Cash $10,726 $8,607 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Temporary cash investments - at cost, \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql which approximates market 57,553 23,705 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total cash and cash equivalents 68,279 32,312 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accounts receivable: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Customer 125,412 73,215 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Allowance for doubtful accounts (2,131) (1,828) \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Associated companies 27,660 1,706 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 22,837 15,030 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accrued unbilled revenues 136,384 90,396 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total receivables 310,162 178,519 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Deferred fuel costs 288,126 134,458 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Fuel inventory - at average cost 37,258 38,271 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Materials and supplies - at average cost 100,018 112,585 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Rate deferrals 5,606 5,606 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Prepayments and other 22,332 21,750 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 831,781 523,501 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql OTHER PROPERTY AND INVESTMENTS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Decommissioning trust funds 243,555 234,677 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Non-utility property - at cost (less accumulated depreciation) 194,422 187,759 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other - at cost (less accumulated depreciation) 14,826 13,681 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 452,803 436,117 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql UTILITY PLANT \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Electric 7,574,905 7,365,407 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Property under capital lease 38,564 46,210 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Natural gas 56,163 52,473 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Construction work in progress 144,814 145,492 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Nuclear fuel under capital lease 57,472 70,801 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL UTILITY PLANT 7,871,918 7,680,383 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Less - accumulated depreciation and amortization 3,664,415 3,534,473 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql UTILITY PLANT - NET 4,207,503 4,145,910 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql DEFERRED DEBITS AND OTHER ASSETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Regulatory assets: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Rate deferrals - 5,606 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql SFAS 109 regulatory asset - net 403,934 385,405 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Unamortized loss on reacquired debt 37,903 40,576 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other regulatory assets 169,405 140,157 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Long-term receivables 29,586 32,260 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 17,349 23,490 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 658,177 627,494 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL ASSETS $6,150,264 $5,733,022 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ========== ========== \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ENTERGY GULF STATES, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql BALANCE SHEETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql LIABILITIES AND SHAREHOLDERS' EQUITY \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql CURRENT LIABILITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Currently maturing long-term debt $122,750 $ - \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accounts payable: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Associated companies 66,312 79,962 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 258,529 114,444 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Customer deposits 37,489 33,360 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Taxes accrued 132,368 101,798 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accumulated deferred income taxes 94,032 27,960 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Nuclear refueling outage costs 10,209 11,216 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Interest accrued 43,539 28,570 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Obligations under capital leases 42,524 51,973 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 19,418 14,557 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 827,170 463,840 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql DEFERRED CREDITS AND OTHER LIABILITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accumulated deferred income taxes 1,115,119 1,098,882 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accumulated deferred investment tax credits 171,000 178,500 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Obligations under capital leases 53,512 65,038 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other regulatory liabilities 16,916 20,089 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Decommissioning 142,604 139,194 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Transition to competition 72,381 47,101 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Regulatory reserves 60,965 110,536 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accumulated provisions 67,404 69,395 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 98,501 117,804 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 1,798,402 1,846,539 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Long-term debt 1,808,879 1,631,581 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Preferred stock with sinking fund 30,758 34,650 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Preference stock - 150,000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Company-obligated mandatorily redeemable \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql preferred securities of subsidiary trust holding \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql solely junior subordinated deferrable debentures 85,000 85,000 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql SHAREHOLDERS' EQUITY \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Preferred stock without sinking fund 47,677 51,444 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Common stock, no par value, authorized 200,000,000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql shares; issued and outstanding 100 shares in 2000 and 1999 114,055 114,055 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Paid-in capital 1,153,195 1,153,131 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Retained earnings 285,128 202,782 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 1,600,055 1,521,412 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Commitments and Contingencies (Notes 2, 9, and 10) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $6,150,264 $5,733,022 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ========== ========== \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql See Notes to Financial Statements. \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY GULF STATES, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql STATEMENTS OF RETAINED EARNINGS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retained Earnings, January 1 $202,782 $202,205 $284,165 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Add: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 180,343 125,000 46,393 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deduct: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Dividends declared: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred and preference stock 9,933 16,784 19,011 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Common stock 88,000 107,000 109,400 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred and preference stock \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql redemption and other 64 639 (58) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total 97,997 124,423 128,353 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retained Earnings, December 31 (Note 8) $285,128 $202,782 $202,205 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ======== ======== ======== \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ENTERGY GULF STATES, INC. AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 1998 1997 1996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Operating revenues $2,511,240 $2,127,208 $1,853,809 $2,147,829 $2,019,181 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Net income (loss) $ 180,343 $ 125,000 $ 46,393 $ 59,976 $ (3,887) \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total assets $6,150,264 $5,733,022 $6,293,744 $6,488,637 $6,421,179 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Long-term obligations (1) $1,978,149 $1,966,269 $1,993,811 $2,098,752 $2,226,329 \par\pard\plain\fs16\par\pard\plain\cf1\f50\fs16\ql (1) Includes long-term debt (excluding currently maturing debt), \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql preferred and preference stock with sinking fund, preferred \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql securities of subsidiary trust, and noncurrent capital lease \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql obligations. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 1998 1997 1996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (Dollars In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Electric Operating Revenues: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Residential $717,453 $607,875 $605,759 $624,862 $612,398 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Commercial 505,346 430,291 422,944 452,724 444,133 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Industrial 870,594 718,779 704,393 740,418 685,178 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Governmental 32,939 28,475 35,930 33,774 31,023 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total retail 2,126,332 1,785,420 1,769,026 1,851,778 1,772,732 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Sales for resale: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Associated companies 93,675 38,416 14,172 14,260 20,783 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Non-associated companies 112,522 109,132 112,182 59,015 76,173 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other (1) 138,355 149,390 (117,796) 136,458 56,300 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total $2,470,884 $2,082,358 $1,777,584 $2,061,511 $1,925,988 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql =========================================================== \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Billed Electric Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Sales (GWH): \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Residential 9,405 8,929 8,903 8,178 8,035 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Commercial 7,660 7,310 6,975 6,575 6,417 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Industrial 17,960 17,684 18,158 18,038 16,661 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Governmental 450 425 560 481 438 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total retail 35,475 34,348 34,596 33,272 31,551 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Sales for resale: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Associated companies 1,381 677 380 414 656 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Non-associated companies 3,248 3,408 3,701 1,503 2,148 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total Electric Department 40,104 38,433 38,677 35,189 34,355 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql =========================================================== \par\pard\plain\fs16\par\pard\plain\cf1\f50\fs16\ql (1) 1998 includes the effects of an Entergy Gulf States reserve for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rate refund. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql Report of Independent Accountants \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql To the Board of Directors and Shareholders of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana, Inc.: \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In our opinion, the accompanying balance sheets and the related statements \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of income, of retained earnings and of cash flows (pages 109 through 113 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and pages 147 through 209) present fairly, in all material respects, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial position of Entergy Louisiana, Inc. at December 31, 2000 and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999, and the results of its operations and its cash flows for each of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql three years in the period ended December 31, 2000 in conformity with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accounting principles generally accepted in the United States of America. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql These financial statements are the responsibility of the Company's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql management; our responsibility is to express an opinion on these financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements based on our audits. We conducted our audits of these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements in accordance with auditing standards generally accepted in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql United States of America, which require that we plan and perform the audit \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to obtain reasonable assurance about whether the financial statements are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql free of material misstatement. An audit includes examining, on a test \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql basis, evidence supporting the amounts and disclosures in the financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements, assessing the accounting principles used and significant \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql estimates made by management, and evaluating the overall financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statement presentation. We believe that our audits provide a reasonable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql basis for our opinion. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PricewaterhouseCoopers LLP \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans, Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql February 1, 2001 \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY LOUISIANA, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net Income \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income decreased in 2000 primarily due to increased depreciation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and amortization costs, increased other operation and maintenance expenses, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and decreased unbilled revenue and other regulatory credits, partially \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql offset by decreased provisions for rate refunds. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income increased in 1999 primarily due to increased unbilled \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql revenue and other regulatory credits, and decreased nuclear refueling \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql outage expenses and interest charges, partially offset by increased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql provisions for rate refunds. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Revenues and Sales \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The changes in electric operating revenues for the twelve months ended \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, 2000 and 1999 are as follows: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Increase/(Decrease) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Description 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Millions) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Base revenues ($4.7) ($48.7) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel cost recovery 270.8 63.6 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales volume/weather 23.9 (5.3) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other revenue (including unbilled) (13.5) 74.5 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales for resale (20.7) 11.6 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------ ----- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total $255.8 $95.7 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ====== ===== \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Base revenues \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, base revenues decreased primarily due to additional formula \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rate plan reductions in the residential, commercial, and industrial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql sectors, partially offset by lower accruals for potential rate refunds. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, base revenues decreased primarily due to accruals for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql potential rate refunds. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel cost recovery revenues \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana is allowed to recover certain fuel and purchased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power costs through fuel mechanisms included in electric rates that are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recorded as fuel cost recovery revenues. The difference between revenues \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql collected and current fuel and purchased power costs is recorded as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deferred fuel costs on Entergy Louisiana's financial statements such that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql these costs generally have no net effect on earnings. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, fuel cost recovery revenues increased as a result of higher \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel and purchased power expenses primarily due to the increased market \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql price of natural gas. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, fuel cost recovery revenues increased due to a shift from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql lower priced nuclear fuel to higher priced gas and purchased power due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql nuclear outages at Waterford 3 in 1999. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY LOUISIANA, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales volume/weather \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, sales volume increased primarily due to more favorable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql weather in the residential and commercial sectors, and increased usage by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql industrial customers. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, sales volume decreased primarily due to less favorable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql weather, partially offset by increased usage by residential and industrial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql customers. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other revenue (including unbilled) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, other revenue decreased primarily due to the effect of a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql change in estimate on 1999 unbilled revenues, in addition to rent received \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for electric property in 1999. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, other revenue increased primarily due to a change in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql estimated unbilled revenues. The changed estimate more closely aligns the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel component of unbilled revenues with regulatory treatment. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales for resale \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, sales for resale decreased as a result of increased sales to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql retail customers resulting in less electricity available for resale. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, sales for resale increased as a result of increased sales to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql affiliates due to outages at affiliate plants, in addition to favorable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql unit prices. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel and purchased power expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, fuel and purchased power expenses increased due to an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increase in the market price of natural gas. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, fuel and purchased power expenses increased due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o higher natural gas prices; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o higher purchased power market prices; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a shift in generation from lower priced nuclear fuel to higher priced \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql gas as a result of refueling and other outages at Waterford 3. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other operation and maintenance expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other operation and maintenance expenses increased in 2000 primarily \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in expenses from maintenance and planned maintenance \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql outages at Waterford 3 and certain fossil plants of $17.9 million; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase of $11 million in outside services employed for legal \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql services for potential rate actions; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in property insurance reserves of $5 million primarily \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to changes in storm damage reserves effective August 1999. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY LOUISIANA, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The overall increase in other operation and maintenance expenses in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 was partially offset by the following: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a decrease in injury and damages claims of $3.5 million; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a decrease of $3 million in benefits expense; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o higher nuclear insurance refunds of $1.8 million. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nuclear refueling outage expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, nuclear refueling outage expenses decreased as a result of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the amortization of higher outage expenses in 1998 due to the extended \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql nuclear refueling outage in 1997. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation and amortization \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, depreciation and amortization expenses increased primarily \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to a review of plant-in-service dates for consistency with regulatory \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql treatment reducing depreciation expense by $3.4 million in August 1999, as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql well as depreciation expense related to net capital additions in 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory charges (credits) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, other regulatory credits decreased due to the LPSC-required \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deferral in 1999 of Year 2000 costs and the amortization of these costs in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000. The deferred costs are being recovered over a five-year period. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other income \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, other income increased primarily due to interest recorded on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deferred fuel costs. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest charges \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000 and 1999, interest on long-term debt decreased primarily due \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to the refinancing and net redemption of $77 million of long-term debt in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999. The decrease in 2000 is partially offset by interest expense \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql incurred on the issuance of $150 million of long-term debt in May 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The effective income tax rates for 2000, 1999, and 1998 were 40.9%, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 38.9%, and 37.8%, respectively. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY LOUISIANA, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INCOME STATEMENTS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING REVENUES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Domestic electric $2,062,437 $1,806,594 $1,710,908 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING EXPENSES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operating and Maintenance: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel, fuel-related expenses, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql gas purchased for resale 560,329 421,763 383,413 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Purchased power 537,589 418,878 372,763 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nuclear refueling outage expenses 13,542 15,756 21,740 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other operation and maintenance 318,841 289,348 289,522 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Decommissioning 10,422 8,786 8,786 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Taxes other than income taxes 77,190 75,447 70,621 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation and amortization 171,204 161,754 162,937 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory charges (credits) - net 960 (5,280) (1,755) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 1,690,077 1,386,452 1,308,027 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING INCOME 372,360 420,142 402,881 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OTHER INCOME \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for equity funds used during construction 4,328 4,925 1,887 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gain on sale of assets - - 2,340 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Miscellaneous - net 6,604 2,206 2,644 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 10,932 7,131 6,871 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INTEREST AND OTHER CHARGES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest on long-term debt 98,655 103,937 109,463 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other interest - net 6,788 7,010 7,127 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Distributions on preferred securities of subsidiary 6,300 6,300 6,300 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for borrowed funds used during construction (3,775) (4,112) (1,729) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 107,968 113,135 121,161 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INCOME BEFORE INCOME TAXES 275,324 314,138 288,591 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes 112,645 122,368 109,104 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql NET INCOME 162,679 191,770 179,487 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred dividend requirements and other 9,514 9,955 13,014 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql EARNINGS APPLICABLE TO \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql COMMON STOCK $153,165 $181,815 $166,473 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ========== ========== ========== \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY LOUISIANA, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql STATEMENTS OF CASH FLOWS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income $162,679 $191,770 $179,487 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Noncash items included in net income: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Reserve for regulatory adjustments 11,456 - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory charges (credits) - net 960 (5,280) (1,754) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation, amortization, and decommissioning 181,626 170,540 171,723 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deferred income taxes and investment tax credits 16,350 (15,487) 26,910 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for equity funds used during construction (4,328) (4,925) (1,887) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gain on sale of assets - - (2,340) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Changes in working capital: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Receivables (97,154) (41,565) (7,972) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accounts payable (11,848) 95,120 (5,878) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Taxes accrued (2,555) 7,659 (7,040) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest accrued 15,300 (33,066) 18,731 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deferred fuel costs (81,890) (9,959) 4,530 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other working capital accounts 38,064 56,714 16,983 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Provision for estimated losses and reserves 6,114 5,442 6,410 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Changes in other regulatory assets 25,400 38,577 (11,443) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 10,249 (45,146) (44,099) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow provided by operating activities 270,423 410,394 342,361 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INVESTING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Construction expenditures (203,049) (130,933) (105,306) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for equity funds used during construction 4,328 4,925 1,887 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nuclear fuel purchases (38,270) (11,308) (38,141) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Proceeds from sale/leaseback of nuclear fuel 38,270 11,308 39,701 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Decommissioning trust contributions and realized \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql change in trust assets (12,299) (13,678) (11,648) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow used in investing activities (211,020) (139,686) (113,507) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FINANCING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Proceeds from issuance of: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term debt 148,736 298,092 112,556 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retirement of: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term debt (100,000) (386,707) (150,786) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Redemption of preferred stock - (50,000) - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Dividends paid: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Common stock (62,400) (197,000) (138,500) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred stock (9,514) (10,389) (13,014) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow used in financing activities (23,178) (346,004) (189,744) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net increase (decrease) in cash and cash equivalents 36,225 (75,296) 39,110 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and cash equivalents at beginning of period 7,734 83,030 43,920 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and cash equivalents at end of period $43,959 $7,734 $83,030 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ======== ======== ======== \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash paid during the period for: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest - net of amount capitalized $89,627 $144,731 $98,801 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes $105,354 $132,924 $86,830 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Noncash investing and financing activities: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Change in unrealized appreciation/(depreciation) of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decommissioning trust assets ($2,979) $4,585 $5,928 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY LOUISIANA, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql BALANCE SHEETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ASSETS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql CURRENT ASSETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and cash equivalents: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash $14,138 $7,734 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Temporary cash investments - at cost, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql which approximates market 29,821 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total cash and cash equivalents 43,959 7,734 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Notes Receivable 1,510 3 \par\pard\plain\fs16\par\pard\plain\f0\fs16\par\pard\plain\cf1\f50\fs16\ql Accounts receivable: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Customer 111,292 79,335 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for doubtful accounts (1,771) (1,615) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Associated companies 30,518 14,601 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 13,698 10,762 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accrued unbilled revenues 152,700 106,200 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total receivables 306,437 209,283 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deferred fuel costs 84,051 2,161 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accumulated deferred income taxes - 12,520 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Materials and supplies - at average cost 77,389 84,027 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deferred nuclear refueling outage costs 16,425 11,336 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Prepayments and other 9,996 6,011 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 539,767 333,075 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OTHER PROPERTY AND INVESTMENTS \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Investment in subsidiary companies - at equity 14,230 14,230 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Decommissioning trust funds 110,263 100,943 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Non-utility property - at cost (less accumulated depreciation) 21,700 21,433 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 146,193 136,606 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql UTILITY PLANT \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Electric 5,357,920 5,178,808 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Property under capital lease 238,427 236,271 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Construction work in progress 85,299 108,106 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nuclear fuel under capital lease 63,923 51,930 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL UTILITY PLANT 5,745,569 5,575,115 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Less - accumulated depreciation and amortization 2,429,495 2,294,394 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql UTILITY PLANT - NET 3,316,074 3,280,721 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql DEFERRED DEBITS AND OTHER ASSETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Regulatory assets: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SFAS 109 regulatory asset - net 204,810 230,899 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Unamortized loss on reacquired debt 33,244 35,856 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory assets 50,881 50,191 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 10,882 17,302 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 299,817 334,248 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL ASSETS $4,301,851 $4,084,650 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ========== ========== \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ENTERGY LOUISIANA, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql BALANCE SHEETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql LIABILITIES AND SHAREHOLDERS' EQUITY \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql CURRENT LIABILITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Currently maturing long-term debt $35,088 $116,388 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accounts payable: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Associated companies 71,948 137,869 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 144,841 90,768 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Customer deposits 60,227 61,096 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Taxes accrued 23,307 25,863 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accumulated deferred income taxes 20,545 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Interest accrued 35,536 20,236 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Obligations under capital leases 34,274 28,387 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 102,614 59,737 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 528,380 540,344 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql DEFERRED CREDITS AND OTHER LIABILITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accumulated deferred income taxes 757,362 792,290 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accumulated deferred investment tax credits 117,393 123,155 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Obligations under capital leases 29,649 23,543 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other regulatory liabilities 12,442 15,421 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Regulatory reserves 11,456 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accumulated provisions 64,201 58,087 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 61,724 34,564 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 1,054,227 1,047,060 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Long-term debt 1,276,696 1,145,463 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Preferred stock with sinking fund 35,000 35,000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Company-obligated mandatorily redeemable \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql preferred securities of subsidiary trust holding \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql solely junior subordinated deferrable debentures 70,000 70,000 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql SHAREHOLDERS' EQUITY \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Preferred stock without sinking fund 100,500 100,500 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Common stock, no par value, authorized 250,000,000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql shares; issued and outstanding 165,173,180 shares in 2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql and 1999 1,088,900 1,088,900 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Capital stock expense and other (2,171) (2,171) \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Retained earnings 150,319 59,554 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 1,337,548 1,246,783 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Commitments and Contingencies (Notes 2, 9, and 10) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $4,301,851 $4,084,650 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ========== ========== \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY LOUISIANA, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql STATEMENTS OF RETAINED EARNINGS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retained Earnings, January 1 $59,554 $74,739 $46,766 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Add: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income 162,679 191,770 179,487 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deduct: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Dividends declared: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred stock 9,514 9,805 13,014 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Common stock 62,400 197,000 138,500 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Capital stock expenses - 150 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- ------- ------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total 71,914 206,955 151,514 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- ------- ------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retained Earnings, December 31 (Note 8) $150,319 $59,554 $74,739 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ======== ======= ======= \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ENTERGY LOUISIANA, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 1998 1997 1996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Operating revenues $2,062,437 $1,806,594 $1,710,908 $1,803,272 $1,828,867 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Net income $ 162,679 $ 191,770 $ 179,487 $ 141,757 $ 190,762 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total assets $4,301,851 $4,084,650 $4,181,041 $4,175,400 $4,279,278 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Long-term obligations (1) $1,411,345 $1,274,006 $1,530,590 $1,522,043 $1,545,889 \par\pard\plain\fs16\par\pard\plain\cf1\f50\fs16\ql (1) Includes long-term debt (excluding currently maturing debt), \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql preferred stock with sinking fund, preferred securities of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql subsidiary trust, and noncurrent capital lease obligations. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 1998 1997 1996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (Dollars In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Electric Operating Revenues: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Residential $716,708 $620,146 $598,573 $606,173 $609,308 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Commercial 441,338 386,042 367,151 379,131 374,515 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Industrial 767,052 646,517 597,536 708,356 727,505 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Governmental 38,772 33,738 32,795 34,171 33,621 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total retail 1,963,870 1,686,443 1,596,055 1,727,831 1,744,949 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Sales for resale: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Associated companies 20,763 27,253 16,002 3,817 5,065 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Non-associated companies 39,704 53,923 53,538 55,345 58,685 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 38,100 38,975 45,313 16,279 20,168 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total $2,062,437 $1,806,594 $1,710,908 $1,803,272 $1,828,867 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql =========================================================== \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Billed Electric Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Sales (GWH): \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Residential 8,648 8,354 8,477 7,826 7,893 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Commercial 5,367 5,221 5,265 4,906 4,846 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Industrial 15,184 15,052 14,781 16,390 17,647 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Governmental 481 468 481 460 457 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total retail 29,680 29,095 29,004 29,582 30,843 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Sales for resale: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Associated companies 228 415 386 104 143 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Non-associated companies 554 831 855 805 982 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ----------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total 30,462 30,341 30,245 30,491 31,968 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql =========================================================== \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Report of Independent Accountants \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql To the Board of Directors and Shareholders of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi, Inc.: \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In our opinion, the accompanying balance sheets and the related statements \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of income, of retained earnings and of cash flows (pages 120 through 125 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and pages 147 through 209) present fairly, in all material respects, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial position of Entergy Mississippi, Inc. at December 31, 2000 and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999, and the results of its operations and its cash flows for each of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql three years in the period ended December 31, 2000 in conformity with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accounting principles generally accepted in the United States of America. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql These financial statements are the responsibility of the Company's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql management; our responsibility is to express an opinion on these financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements based on our audits. We conducted our audits of these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements in accordance with auditing standards generally accepted in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql United States of America, which require that we plan and perform the audit \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to obtain reasonable assurance about whether the financial statements are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql free of material misstatement. An audit includes examining, on a test \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql basis, evidence supporting the amounts and disclosures in the financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements, assessing the accounting principles used and significant \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql estimates made by management, and evaluating the overall financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statement presentation. We believe that our audits provide a reasonable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql basis for our opinion. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PricewaterhouseCoopers LLP \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans, Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql February 1, 2001 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY MISSISSIPPI, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net Income \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income decreased in 2000 primarily due to increases in other \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operation and maintenance expenses, interest expense, depreciation expense, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and an increase in the effective income tax rate. These decreases were \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql partially offset by increases in unbilled revenues and sales volume. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income decreased in 1999 primarily due to a decrease in unbilled \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql revenues and an increase in other operation and maintenance expenses. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Revenues and Sales \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The changes in electric operating revenues for the twelve months ended \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, 2000 and 1999 are as follows: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Increase/(Decrease) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Description 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Millions) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Base revenues ($3.8) ($9.7) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Grand Gulf rate rider 4.7 (95.9) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel cost recovery 54.8 (11.6) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales volume/weather 9.6 4.1 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other revenue (including unbilled) 23.9 (12.1) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales for resale 15.4 (18.3) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------ ------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total $104.6 ($143.5) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ====== ======= \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Base revenues \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Base revenues decreased in 2000 primarily due to an annual rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reduction of $13.3 million under the formula rate plan, which was effective \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql May 1999. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Base revenues decreased in 1999 primarily due to the May 1999 rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reduction and an annual rate reduction of $6.6 million under the formula \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rate plan, which was effective May 1998. The formula rate plan reduction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql is discussed in more detail in Note 2 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Grand Gulf rate rider \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Rate rider revenues have no material effect on net income because \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql specific incurred expenses offset them. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, Grand Gulf rate rider revenue decreased as a result of a new \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rider which became effective October 1, 1998. This new rider eliminated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql revenues attributable to the Grand Gulf phase-in plan, which was completed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in September 1998. However, this decrease was partially offset by the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Grand Gulf Accelerated Recovery Tariff (GGART), which also became effective \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql October 1, 1998. This tariff provides for accelerated recovery of a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql portion of Entergy Mississippi's Grand Gulf purchased power obligation. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The GGART is discussed in more detail in Note 2 to the financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY MISSISSIPPI, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel cost recovery \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi is allowed to recover certain fuel and purchased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power costs through fuel mechanisms included in electric rates, recorded as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel cost recovery revenues. The difference between revenues collected and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql current fuel and purchased power costs is recorded as deferred fuel costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql on Entergy Mississippi's financial statements such that these costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generally have no net effect on earnings. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, fuel cost recovery revenues increased primarily due to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MPSC's review and subsequent increase of Entergy Mississippi's energy cost \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovery rider effective in January 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, fuel cost recovery revenues decreased primarily due to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MPSC's review and subsequent decrease of Entergy Mississippi's energy cost \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovery rider effective in January 1999. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales volume/weather \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, sales volume increased as a result of increased usage in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql residential and commercial sectors, as well as the effect of more favorable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql weather in the residential sector. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, sales volume increased as a result of sales growth in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql residential and commercial sectors, partially offset by unfavorable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql weather. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other revenue (including unbilled) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, other revenue increased primarily due to the effect of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql favorable weather in 2000 and the effect of a change in estimate on 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql unbilled revenues. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, other revenue decreased primarily due to the effect of a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql change in estimate on unbilled revenues. The changed estimate more closely \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql aligned the fuel component of unbilled revenues with regulatory treatment. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales for resale \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, sales for resale increased primarily due to an increase in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the average price of energy supplied for resale sales. The increase was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql partially offset by less energy available for resale sales due to plant \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql outages early in 2000, which resulted in lower sales volume. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, sales for resale decreased as a result of decreased oil \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generation due to plant outages. The decrease is also due to higher sales \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to associated companies in 1998 as a result of an outage at Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel and purchased power expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, fuel and purchased power expenses increased primarily due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql an increase in the market prices of oil and natural gas. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY MISSISSIPPI, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, fuel and purchased power expenses decreased primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a decrease in total energy consumption requirements; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o planned and unplanned plant outages during the year. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The decrease in fuel and purchased power expenses in 1999 was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql partially offset by: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a shift from lower priced oil generation to higher priced gas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generation as a result of plant outages in 1999; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in the market price of purchased power; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the GGART implemented by System Energy in October 1998 resulting in an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increase in the price of System Energy purchased power. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other operation and maintenance \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, other operation and maintenance expenses increased primarily \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in property insurance expense of $9.3 million primarily \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to a change in storm damage reserve amortization in accordance \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with regulatory treatment; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in maintenance of electric plant of $7.0 million. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, other operation and maintenance expenses increased primarily \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o planned and unplanned plant outages in 1999 of $9.1 million; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in customer service and reliability improvement spending \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of $4.0 million; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in employee benefit expense of $3.8 million; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in casualty reserves of $4.2 million. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation and Amortization \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, depreciation and amortization expenses increased due to a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql review of plant-in-service dates for consistency with regulatory treatment \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reducing depreciation expense by $2.6 million in August 1999. Capital \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql additions in 1999 and 2000 also contributed to the increase. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory credits \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, other regulatory credits decreased due to a decrease in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deferral of Grand Gulf 1 expenses associated with the System Energy rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increase. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, other regulatory credits increased due to greater under- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovery of Grand Gulf 1 related costs as a result of the new rider \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql implemented in October 1998. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Amortization of rate deferrals \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, amortization of rate deferrals decreased due to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql completion of the Grand Gulf 1 rate phase-in plan in September 1998. These \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql phase-ins had no material effect on net income. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY MISSISSIPPI, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest and other charges \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest on long-term debt increased in 2000 primarily due to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql issuance of $120 million of long-term debt in February 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest on long-term debt decreased in 1999 primarily due to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql refinancing of certain long-term debt. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The effective income tax rates for 2000, 1999, and 1998 were 37.0%, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 29.7%, and 30.9%, respectively. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The increase in the effective income tax rate in 2000 is due to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql effect that the distribution of the Entergy Corporation income tax benefit \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql had on the 1999 effective income tax rate. In 1999, a tax benefit was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql booked related to the 1998 tax return. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ENTERGY MISSISSIPPI, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql INCOME STATEMENTS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql OPERATING REVENUES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Domestic electric $937,371 $832,819 $976,300 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql OPERATING EXPENSES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Operating and Maintenance: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Fuel, fuel-related expenses, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql gas purchased for resale 221,075 185,063 241,415 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Purchased power 366,491 332,015 286,769 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other operation and maintenance 168,432 152,817 131,752 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Taxes other than income taxes 45,436 44,013 44,888 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Depreciation and amortization 49,046 42,870 45,133 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other regulatory credits - net (6,872) (12,044) (3,186) \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Amortization of rate deferrals - - 104,969 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 843,608 744,734 851,740 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql OPERATING INCOME 93,763 88,085 124,560 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql OTHER INCOME \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Allowance for equity funds used during construction 2,385 1,569 188 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Gain on sale of assets 19 - 1,025 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Miscellaneous - net 8,680 6,781 4,891 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 11,084 8,350 6,104 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql INTEREST AND OTHER CHARGES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Interest on long-term debt 41,583 35,265 37,756 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other interest - net 3,294 3,574 3,171 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Allowance for borrowed funds used during construction (1,871) (1,529) (932) \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 43,006 37,310 39,995 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql INCOME BEFORE INCOME TAXES 61,841 59,125 90,669 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Income taxes 22,868 17,537 28,031 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql NET INCOME 38,973 41,588 62,638 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Preferred dividend requirements and other 3,370 3,370 3,370 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql EARNINGS APPLICABLE TO \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql COMMON STOCK $35,603 $38,218 $59,268 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ======== ======== ======== \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY MISSISSIPPI, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql STATEMENTS OF CASH FLOWS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income $38,973 $41,588 $62,638 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Noncash items included in net income: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Amortization of rate deferrals - - 104,969 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory credits - net (6,872) (12,044) (3,186) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation and amortization 49,046 42,870 45,133 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deferred income taxes and investment tax credits 51,081 18,066 (12,494) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for equity funds used during construction (2,385) (1,569) (188) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gain (loss) on sale of assets (19) - (1,025) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Changes in working capital: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Receivables (30,628) 24,208 6,253 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel inventory 338 (771) 384 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accounts payable 3,064 54,317 (31,967) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Taxes accrued (4,106) 29,955 (26,301) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest accrued 3,062 (4,595) 323 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deferred fuel costs 47,939 (45,830) 12,858 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other working capital accounts 6,160 10,072 8,652 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Provision for estimated losses and reserves (568) 4,173 (6,915) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Changes in other regulatory assets (9,929) (30,179) (38,295) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 37,105 12,152 4,202 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow provided by operating activities 182,261 142,413 125,041 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INVESTING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Construction expenditures (121,252) (94,717) (58,705) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for equity funds used during construction 2,385 1,569 188 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory investments (160,611) - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow used in investing activities (279,478) (93,148) (58,517) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FINANCING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Proceeds from issuance of: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term debt 118,913 153,629 78,703 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retirement of: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term debt - (163,278) (80,020) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Changes in short-term borrowing, net - (6) (13) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Dividends paid: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Common stock (18,000) (34,100) (66,000) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred stock (3,370) (3,363) (3,370) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow provided by (used in) financing activities 97,543 (47,118) (70,700) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net increase in cash and cash equivalents 326 2,147 (4,176) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and cash equivalents at beginning of period 4,787 2,640 6,816 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and cash equivalents at end of period $5,113 $4,787 $2,640 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ======== ======== ======== \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash paid/(received) during the period for: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest - net of amount capitalized $39,569 $41,567 $39,291 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes ($23,763) ($29,850) $64,204 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ENTERGY MISSISSIPPI, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql BALANCE SHEETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ASSETS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql CURRENT ASSETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Cash and cash equivalents $5,113 $4,787 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accounts receivable: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Customer 44,517 35,675 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Allowance for doubtful accounts (1,044) (886) \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Associated companies 10,741 1,370 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 9,964 2,391 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accrued unbilled revenues 33,600 28,600 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total receivables 97,778 67,150 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Deferred fuel costs 64,950 47,939 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Fuel inventory - at average cost 3,436 3,774 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Materials and supplies - at average cost 18,485 17,068 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Prepayments and other 3,004 7,114 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 192,766 147,832 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql OTHER PROPERTY AND INVESTMENTS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Investment in subsidiary companies - at equity 5,531 5,531 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Non-utility property - at cost (less accumulated depreciation) 6,851 6,965 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 12,382 12,496 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql UTILITY PLANT \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Electric 1,885,501 1,763,636 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Property under capital lease 290 384 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Construction work in progress 44,085 66,789 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL UTILITY PLANT 1,929,876 1,830,809 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Less - accumulated depreciation and amortization 733,977 709,543 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql UTILITY PLANT - NET 1,195,899 1,121,266 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql DEFERRED DEBITS AND OTHER ASSETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Regulatory assets: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql SFAS 109 regulatory asset - net 25,544 24,051 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Unamortized loss on reacquired debt 15,122 16,345 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Deferred fuel costs 95,661 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other regulatory assets 140,679 132,243 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 5,886 5,784 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 282,892 178,423 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL ASSETS $1,683,939 $1,460,017 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ========== ========== \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql See Notes to Financial Statements. \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY MISSISSIPPI, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql BALANCE SHEETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LIABILITIES AND SHAREHOLDERS' EQUITY \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql CURRENT LIABILITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accounts payable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Associated companies $92,980 $84,382 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 26,933 32,470 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Customer deposits 26,368 23,303 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Taxes accrued 31,862 35,968 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accumulated deferred income taxes 47,734 526 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest accrued 13,099 10,038 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Obligations under capital leases 79 95 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 2,540 2,137 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 241,595 188,919 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql DEFERRED CREDITS AND OTHER LIABILITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accumulated deferred income taxes 306,295 298,477 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accumulated deferred investment tax credits 19,408 20,908 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Obligations under capital leases 211 290 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accumulated provisions 6,806 7,374 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 31,339 3,368 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 364,059 330,417 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term debt 584,467 464,466 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SHAREHOLDERS' EQUITY \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred stock without sinking fund 50,381 50,381 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Common stock, no par value, authorized 15,000,000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql shares; issued and outstanding 8,666,357 shares in 2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and 1999 199,326 199,326 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Capital stock expense and other (59) (59) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retained earnings 244,170 226,567 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 493,818 476,215 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Commitments and Contingencies (Notes 2, 9, and 10) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $1,683,939 $1,460,017 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ========== ========== \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY MISSISSIPPI, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql STATEMENTS OF RETAINED EARNINGS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retained Earnings, January 1 $226,567 $222,449 $229,181 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Add: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income 38,973 41,588 62,638 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deduct: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Dividends declared: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred stock 3,370 3,370 3,370 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Common stock 18,000 34,100 66,000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total 21,370 37,470 69,370 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retained Earnings, December 31 (Note 8) $244,170 $226,567 $222,449 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ======== ======== ======== \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ENTERGY MISSISSIPPI, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 1998 1997 1996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Operating revenues $ 937,371 $ 832,819 $ 976,300 $ 937,395 $ 958,430 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Net Income $ 38,973 $ 41,588 $ 62,638 $ 66,661 $ 79,211 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total assets $1,683,939 $1,460,017 $1,350,929 $1,439,561 $1,521,466 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Long-term obligations (1) $ 584,678 $ 464,756 $ 464,000 $ 464,156 $ 406,054 \par\pard\plain\fs16\par\pard\plain\cf1\f50\fs16\ql (1) Includes long-term debt (excluding currently maturing debt) and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql noncurrent capital lease obligations. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 1997 1996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (Dollars In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Electric Operating Revenues: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Residential $340,691 $311,003 $367,895 $342,818 $358,264 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Commercial 275,010 250,929 284,787 274,195 281,626 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Industrial 161,065 151,659 170,910 173,152 185,351 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Governmental 25,612 23,528 26,670 26,882 29,093 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total retail 802,378 737,119 850,262 817,047 854,334 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales for resale: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Associated companies 82,844 63,004 80,357 78,233 58,749 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Non-associated companies 27,058 31,546 32,442 21,276 22,814 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 25,091 1,150 13,239 20,839 22,533 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total $937,371 $832,819 $976,300 $937,395 $958,430 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ================================================= \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Billed Electric Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales (GWH): \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Residential 4,976 4,753 4,800 4,323 4,355 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Commercial 4,307 4,156 4,015 3,673 3,508 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Industrial 3,188 3,246 3,163 3,089 3,063 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Governmental 376 363 347 333 346 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total retail 12,847 12,518 12,325 11,418 11,272 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales for resale: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Associated companies 1,276 1,774 2,424 1,918 1,368 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Non-associated companies 313 426 484 412 521 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total 14,436 14,718 15,233 13,748 13,161 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ================================================= \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\f0\fs16\par\pard\plain\cf1\f50\fs16\ql Report of Independent Accountants \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql To the Board of Directors and Shareholders of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans, Inc.: \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In our opinion, the accompanying balance sheets and the related statements \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of income, of retained earnings and of cash flows (pages 131 through 135 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and pages 147 through 209) present fairly, in all material respects, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial position of Entergy New Orleans, Inc. at December 31, 2000 and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999, and the results of its operations and its cash flows for each of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql three years in the period ended December 31, 2000 in conformity with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accounting principles generally accepted in the United States of America. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql These financial statements are the responsibility of the Company's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql management; our responsibility is to express an opinion on these financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements based on our audits. We conducted our audits of these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements in accordance with auditing standards generally accepted in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql United States of America, which require that we plan and perform the audit \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to obtain reasonable assurance about whether the financial statements are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql free of material misstatement. An audit includes examining, on a test \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql basis, evidence supporting the amounts and disclosures in the financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements, assessing the accounting principles used and significant \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql estimates made by management, and evaluating the overall financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statement presentation. We believe that our audits provide a reasonable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql basis for our opinion. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PricewaterhouseCoopers LLP \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans, Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql February 1, 2001 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY NEW ORLEANS, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net Income \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income decreased slightly in 2000 primarily due to increased other \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operation and maintenance expenses. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income increased slightly in 1999 primarily due to an increase in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql unbilled revenues and sales volume, partially offset by an increase in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql other operation and maintenance expenses. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Revenues and Sales \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Electric operating revenues \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The changes in electric operating revenues for the twelve months \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ended December 31, 2000 and 1999 are as follows: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Increase/(Decrease) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Description 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Millions) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Base revenues $4.0 ($11.3) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel cost recovery 62.6 (4.6) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales volume/weather 2.1 1.7 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other revenue (including unbilled) 4.2 5.5 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales for resale 15.4 3.7 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ----- ----- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total $88.3 ($5.0) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ===== ===== \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Base revenues \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, base revenues increased primarily due to a decrease in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql provision for rate refunds accrued for potential rate matters. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, base revenues decreased primarily due to base rate reductions \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql effective January 1999 and rate refund provisions accrued for potential \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rate matters. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel cost recovery \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans is allowed to recover certain fuel and purchased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power costs through fuel mechanisms included in electric rates, recorded as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel cost recovery revenues. The difference between revenues collected and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql current fuel and purchased power costs is recorded as deferred fuel costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql on Entergy New Orleans' financial statements such that these costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generally have no effect on earnings. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, fuel cost recovery increased primarily due to the increased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql market price of natural gas. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, fuel cost recovery revenues decreased due to an under- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovery of fuel expenses resulting from higher market prices in 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql compared to the prior year. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY NEW ORLEANS, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other revenue (including unbilled) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000 and 1999, other revenue increased primarily due to the effect \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of favorable weather and higher fuel and purchased power costs on unbilled \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql revenues. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales for resale \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, sales for resale increased due to an increase in the average \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql price of electricity supplied for resale sales, coupled with an increase in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql affiliated sales volume. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, sales for resale increased due to favorable unit prices \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql resulting from increased purchased power and gas market prices, coupled \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with an increase in affiliated sales volume. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gas operating revenues \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, gas operating revenues increased primarily due to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increased market price of natural gas. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel and purchased power expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, fuel and purchased power expenses increased primarily due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the increased market price of natural gas. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other operation and maintenance expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, other operation and maintenance expenses increased primarily \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in uncollectible accounts expense for miscellaneous accounts \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql receivable of $1.3 million; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in maintenance of fossil plants of $1.1 million; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in advertising expenses of $1.3 million. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, other operation and maintenance expenses increased primarily \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in spending for customer service and reliability \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql improvements of $3.0 million; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in customer collection expenses of $2.2 million. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Taxes other than income taxes \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, taxes other than income taxes increased primarily due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increased local franchise taxes as a result of higher revenue. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql ENTERGY NEW ORLEANS, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory credits \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, other regulatory credits decreased due to an over-recovery of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Grand Gulf 1 related costs in 2000 compared to an under-recovery in 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and the deferral of Year 2000 costs in 1999. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, other regulatory credits increased due to a greater under- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovery of Grand Gulf 1 costs in 1999. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Amortization of rate deferrals \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000 and 1999, amortization of rate deferrals decreased due to a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql scheduled rate change in the amortization of Grand Gulf 1 phase-in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expenses. The Grand Gulf 1 phase-in plan will be completed in 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other income \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other income increased in 1999 primarily due to: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an increase in AFUDC resulting from increased capital charges on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql projects in 1999; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o increased interest related to the Grand Gulf 1 rate deferral plan. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The Grand Gulf 1 rate deferral plan is discussed in more detail in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Note 2 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest and other charges \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, interest on long-term debt increased primarily due to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql issuance of $30 million of long-term debt in July 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The effective income tax rates for 2000, 1999, and 1998 were 41.2%, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 40.7%, and 38.4% respectively. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The increase in the effective income tax rate for 1999 was primarily \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to the increase in pre-tax income reducing the impact of permanent \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql differences and flow through items. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY NEW ORLEANS, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INCOME STATEMENTS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING REVENUES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Domestic electric $514,774 $426,431 $431,453 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Natural gas 125,516 81,357 82,297 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 640,290 507,788 513,750 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING EXPENSES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operating and Maintenance: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel, fuel-related expenses, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql gas purchased for resale 253,869 135,242 138,142 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Purchased power 173,371 166,579 164,435 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other operation and maintenance 87,254 83,197 79,023 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Taxes other than income taxes 45,132 39,621 40,417 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation and amortization 23,550 21,219 21,878 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory credits - net (7,058) (9,036) (4,540) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Amortization of rate deferrals 24,786 28,430 35,336 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 600,904 465,252 474,691 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING INCOME 39,386 42,536 39,059 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OTHER INCOME \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for equity funds used during construction 1,190 1,084 284 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gain on sale of assets - - 458 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Miscellaneous - net 2,530 2,263 951 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 3,720 3,347 1,693 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INTEREST AND OTHER CHARGES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest on long-term debt 14,429 13,277 13,717 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other interest - net 1,462 1,403 1,075 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for borrowed funds used during construction (900) (788) (219) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 14,991 13,892 14,573 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INCOME BEFORE INCOME TAXES 28,115 31,991 26,179 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes 11,597 13,030 10,042 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql NET INCOME 16,518 18,961 16,137 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred dividend requirements and other 965 965 965 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql EARNINGS APPLICABLE TO \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql COMMON STOCK $15,553 $17,996 $15,172 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ======== ======== ======== \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY NEW ORLEANS, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql STATEMENTS OF CASH FLOWS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income $16,518 $18,961 $16,137 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Noncash items included in net income: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Amortization of rate deferrals 24,786 28,430 35,336 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory credits - net (7,058) (9,036) (4,540) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation and amortization 23,550 21,219 21,878 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deferred income taxes and investment tax credits (639) (3,131) (7,498) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for equity funds used during construction (1,190) (1,084) (284) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gain on sale of assets - - (458) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Changes in working capital: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Receivables (45,580) (7,258) 3,148 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel inventory (911) 179 (861) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accounts payable 29,592 23,319 (4,136) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Taxes accrued 5,394 429 (5,270) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest accrued 1,163 37 (130) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deferred fuel costs (13,751) (13,293) 8,193 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other working capital accounts (223) 6,607 (5,122) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Provision for estimated losses and reserves (365) (531) (6,295) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Changes in other regulatory assets (11,637) (11,482) (6,964) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 10,812 6,796 (2,805) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow provided by operating activities 30,461 60,162 40,329 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INVESTING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Construction expenditures (48,902) (46,239) (21,691) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for equity funds used during construction 1,190 1,084 284 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow used in investing activities (47,712) (45,155) (21,407) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FINANCING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Proceeds from issuance of: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term debt 29,564 - 29,438 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retirement of: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term debt - - (30,000) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Dividends paid: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Common stock (9,500) (26,500) (9,700) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred stock (965) (1,206) (965) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow provided by (used in) financing activities 19,099 (27,706) (11,227) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net increase (decrease) in cash and cash equivalents 1,848 (12,699) 7,695 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and cash equivalents at beginning of period 4,454 17,153 9,458 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and cash equivalents at end of period $6,302 $4,454 $17,153 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ======== ======== ======== \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash paid during the period for: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest - net of amount capitalized $14,331 $14,281 $14,592 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes - net $9,207 $12,476 $26,197 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY NEW ORLEANS, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql BALANCE SHEETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ASSETS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql CURRENT ASSETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and cash equivalents: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash $6,302 $4,454 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accounts receivable: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Customer 67,264 28,658 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for doubtful accounts (770) (846) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Associated companies 2,800 404 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 3,709 6,225 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accrued unbilled revenues 26,838 19,820 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total receivables 99,841 54,261 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deferred fuel costs 28,234 14,483 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel inventory - at average cost 4,204 3,293 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Materials and supplies - at average cost 9,630 10,127 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Rate deferrals 10,974 24,788 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Prepayments and other 1,416 2,528 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 160,601 113,934 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OTHER PROPERTY AND INVESTMENTS \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Investment in subsidiary companies - at equity 3,259 3,259 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql UTILITY PLANT \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Electric 572,061 541,525 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Natural gas 134,826 133,568 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Construction work in progress 36,489 29,780 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL UTILITY PLANT 743,376 704,873 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Less - accumulated depreciation and amortization 394,271 382,797 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql UTILITY PLANT - NET 349,105 322,076 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql DEFERRED DEBITS AND OTHER ASSETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Regulatory assets: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Rate deferrals - 10,974 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Unamortized loss on reacquired debt 974 1,187 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory assets 44,676 33,039 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 616 1,277 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 46,266 46,477 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL ASSETS $559,231 $485,746 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ======== ======== \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY NEW ORLEANS, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql BALANCE SHEETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LIABILITIES AND SHAREHOLDERS' EQUITY \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql CURRENT LIABILITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accounts payable: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Associated companies $24,637 $24,350 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 57,566 28,261 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Customer deposits 18,311 17,830 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Taxes accrued 5,823 429 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accumulated deferred income taxes 6,543 10,863 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest accrued 6,119 4,956 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 3,211 5,524 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 122,210 92,213 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql DEFERRED CREDITS AND OTHER LIABILITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accumulated deferred income taxes 43,754 43,878 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accumulated deferred investment tax credits 5,868 6,378 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SFAS 109 regulatory liability - net 12,607 7,528 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory liabilities 537 1,753 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accumulated provisions 8,471 8,836 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 12,356 7,733 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 83,593 76,106 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term debt 199,031 169,083 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SHAREHOLDERS' EQUITY \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred stock without sinking fund 19,780 19,780 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Common stock, $4 par value, authorized 10,000,000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql shares; issued and outstanding 8,435,900 shares in 2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and 1999 33,744 33,744 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Paid-in capital 36,294 36,294 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retained earnings 64,579 58,526 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 154,397 148,344 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Commitments and Contingencies (Notes 2 and 9) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $559,231 $485,746 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ======== ======== \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\f0\fs16\par\pard\plain\cf1\f50\fs16\ql ENTERGY NEW ORLEANS, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql STATEMENTS OF RETAINED EARNINGS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retained Earnings, January 1 $58,526 $67,030 $61,558 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Add: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income 16,518 18,961 16,137 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deduct: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Dividends declared: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Preferred stock 965 965 965 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Common stock 9,500 26,500 9,700 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------- ------- ------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total 10,465 27,465 10,665 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------- ------- ------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retained Earnings, December 31 (Note 8) $64,579 $58,526 $67,030 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ======= ======= ======= \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY NEW ORLEANS, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 1997 1996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operating revenues $640,290 $507,788 $513,750 $504,822 $504,277 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net Income $ 16,518 $ 18,961 $ 16,137 $ 15,451 $ 26,776 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total assets $559,231 $485,746 $471,904 $498,150 $549,996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term obligations (1) $199,031 $169,083 $169,018 $168,953 $168,888 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (1) Includes long-term debt (excluding currently maturing debt). \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 1997 1996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (Dollars In Thousands) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Electric Operating Revenues: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Residential $188,314 $158,822 $164,765 $145,688 $151,577 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Commercial 170,684 146,328 149,353 143,113 149,649 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Industrial 25,479 25,584 26,229 24,616 24,663 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Governmental 73,028 63,056 62,332 58,746 58,561 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total retail 457,505 393,790 402,679 372,163 384,450 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales for resale: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Associated companies 31,629 14,207 10,451 10,342 2,649 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Non-associated companies 8,504 10,545 10,590 8,996 9,882 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 17,136 7,889 7,733 18,630 6,273 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total $514,774 $426,431 $431,453 $410,131 $403,254 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ================================================= \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Billed Electric Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales (GWH): \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Residential 2,178 2,102 2,141 1,971 1,998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Commercial 2,260 2,208 2,149 2,072 2,073 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Industrial 384 514 514 484 481 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Governmental 1,058 1,071 1,037 994 974 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total retail 5,880 5,895 5,841 5,521 5,526 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Sales for resale: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Associated companies 570 441 370 316 66 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Non-associated companies 141 180 199 160 212 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total 6,591 6,516 6,410 5,997 5,804 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ================================================= \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql Report of Independent Accountants \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql To the Board of Directors and Shareholder of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy Resources, Inc.: \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In our opinion, the accompanying balance sheets and the related statements \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of income, of retained earnings and of cash flows (pages 140 through 145 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and pages 147 through 209) present fairly, in all material respects, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial position of System Energy Resources, Inc. at December 31, 2000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and 1999, and the results of its operations and its cash flows for each of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the three years in the period ended December 31, 2000 in conformity with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accounting principles generally accepted in the United States of America. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql These financial statements are the responsibility of the Company's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql management; our responsibility is to express an opinion on these financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements based on our audits. We conducted our audits of these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements in accordance with auditing standards generally accepted in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql United States of America, which require that we plan and perform the audit \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to obtain reasonable assurance about whether the financial statements are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql free of material misstatement. An audit includes examining, on a test \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql basis, evidence supporting the amounts and disclosures in the financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements, assessing the accounting principles used and significant \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql estimates made by management, and evaluating the overall financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statement presentation. We believe that our audits provide a reasonable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql basis for our opinion. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PricewaterhouseCoopers LLP \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans, Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql February 1, 2001 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\cf1\f50\fs16\ql SYSTEM ENERGY RESOURCES, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net Income \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income increased in 2000 due to increased interest earnings from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the money pool, an inter-company funding arrangement, and decreased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql interest expense associated with the potential refund of System Energy's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql proposed rate increase. This increase in net income was partially offset \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by a higher effective income tax rate in 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income decreased in 1999 due to the additional reserves and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql interest recorded for the potential refund of System Energy's proposed rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increase, as well as downtime for unplanned outages. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Revenues \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operating revenues recover operating expenses, depreciation, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql capital costs attributable to Grand Gulf 1. Capital costs are computed by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql allowing a return on System Energy's common equity funds allocable to its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql net investment in Grand Gulf 1 and adding to such amount System Energy's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql effective interest cost for its debt. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operating revenues increased in 2000 primarily due to an increase in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recoverable expenses. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operating revenues increased in 1999 primarily due to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql implementation of the Grand Gulf Accelerated Recovery Tariff (GGART) at \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas and Entergy Mississippi. This increase in revenues is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql offset by related regulatory charges and does not affect net income. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql tariff was designed to allow Entergy Arkansas and Entergy Mississippi to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accelerate the payment of a portion of their Grand Gulf purchased power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql obligation in advance of the implementation of retail access. It became \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql effective on January 1, 1999 and October 1, 1998 for Entergy Arkansas and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi, respectively. The GGART and System Energy's proposed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rate increase, which is subject to refund, are discussed in Note 2 to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel expenses \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, fuel expenses increased primarily due to increased nuclear \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel burn as a result of Grand Gulf 1 being operational 358 days, as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql compared to 295 days in 1999. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, fuel expenses decreased primarily due to an extended nuclear \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql refueling outage at Grand Gulf 1 in addition to unplanned outages. Grand \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf 1 was on-line for 17 fewer days in 1999 compared to 1998. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation and amortization \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 2000, depreciation expense increased due to higher depreciation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql associated with the principal payment on the sale and leaseback of a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql portion of Grand Gulf 1. The depreciation schedule matches the collection \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of lease principal and revenues with the depreciation of the asset. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In 1999, depreciation and amortization expenses decreased as a result \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the reduction in principal payment associated with the sale and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql leaseback of a portion of Grand Gulf 1. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SYSTEM ENERGY RESOURCES, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql RESULTS OF OPERATIONS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory charges \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In both 2000 and 1999, other regulatory charges increased due to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql implementation of the GGART at Entergy Arkansas and Entergy Mississippi, as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql discussed above. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other income \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other income increased in 2000 and 1999 as a result of the interest \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql earned on System Energy's advances to the money pool, an inter-company \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql funding arrangement. The money pool is discussed in Note 4 to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest charges \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest on long-term debt decreased in 2000 and 1999 as a result of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the retirement and refinancing of higher-cost long-term debt. In 2000, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy retired $75 million of debenture bonds. In 1999, System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Energy retired $160 million of first mortgage bonds and refinanced $102 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million of governmental bonds at an annual interest rate of 5.9%. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other interest decreased in 2000 primarily due to decreased interest \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expense recorded on the potential refund of System Energy's proposed rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increase. Other interest increased in 1999 due to interest on the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql potential refund of System Energy's proposed rate increase. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The effective income tax rates in 2000, 1999, and 1998 were 46.4%, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 39.5%, and 42.1%, respectively. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The effective income tax rate for 2000, increased primarily due to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increased pre-tax income and the amortization of investment tax credits \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql related to Grand Gulf 2 in 1999. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql SYSTEM ENERGY RESOURCES, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql INCOME STATEMENTS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql OPERATING REVENUES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Domestic electric $656,749 $620,032 $602,373 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql OPERATING EXPENSES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Operating and Maintenance: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Fuel, fuel-related expenses, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql gas purchased for resale 42,369 37,336 41,740 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Nuclear refueling outage expenses 14,423 14,136 15,737 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other operation and maintenance 88,257 87,450 86,696 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Decommissioning 18,944 18,944 18,944 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Taxes other than income taxes 30,517 27,212 26,839 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Depreciation and amortization 127,904 113,862 125,331 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other regulatory charges - net 63,590 57,656 4,443 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 386,004 356,596 319,730 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql OPERATING INCOME 270,745 263,436 282,643 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql OTHER INCOME \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Allowance for equity funds used during construction 1,482 2,540 2,042 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Miscellaneous - net 20,446 16,309 13,309 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 21,928 18,849 15,351 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql INTEREST AND OTHER CHARGES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Interest on long-term debt 87,689 102,764 109,735 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other interest - net 30,830 45,218 6,325 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Allowance for borrowed funds used during construction (854) (1,920) (1,805) \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 117,665 146,062 114,255 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql INCOME BEFORE INCOME TAXES 175,008 136,223 183,739 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Income taxes 81,263 53,851 77,263 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql NET INCOME $93,745 $82,372 $106,476 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ======== ======== ======== \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql See Notes to Financial Statements. \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SYSTEM ENERGY RESOURCES, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql STATEMENTS OF CASH FLOWS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OPERATING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income $93,745 $82,372 $106,476 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Noncash items included in net income: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Reserve for regulatory adjustments 54,598 108,484 68,236 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory charges - net 63,590 57,656 4,443 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation, amortization, and decommissioning 146,848 132,806 144,275 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deferred income taxes and investment tax credits (71,212) (86,860) (28,222) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for equity funds used during construction (1,482) (2,540) (2,042) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Changes in working capital: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Receivables 87,212 (172,354) 9,690 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accounts payable (7,401) (11,688) (2,859) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Taxes accrued 13,147 (21,424) 1,131 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest accrued 4,008 (2,022) (300) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other working capital accounts 20,754 (4,425) (2,228) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Provision for estimated losses and reserves (1,328) 45 (1,704) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Changes in other regulatory assets 58,592 (18,492) 25,066 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other (65,491) 41,250 (23,159) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow provided by operating activities 395,580 102,808 298,803 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql INVESTING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Construction expenditures (36,555) (28,848) (30,692) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Allowance for equity funds used during construction 1,482 2,540 2,042 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nuclear fuel purchases - (39,975) (30,523) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Proceeds from sale/leaseback of nuclear fuel - 39,975 30,523 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Decommissioning trust contributions and realized \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql change in trust assets (23,694) (22,139) (24,166) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow used in investing activities (58,767) (48,447) (52,816) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FINANCING ACTIVITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Proceeds from issuance of: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term debt - 101,835 212,976 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retirement of: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Long-term debt (77,947) (282,885) (300,341) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Dividends paid: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Common stock (91,800) (75,000) (72,300) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net cash flow used in financing activities (169,747) (256,050) (159,665) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net increase (decrease) in cash and cash equivalents 167,066 (201,689) 86,322 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and cash equivalents at beginning of period 35,152 236,841 150,519 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and cash equivalents at end of period $202,218 $35,152 $236,841 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ======== ======== ======== \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash paid during the period for: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Interest - net of amount capitalized $109,046 $141,731 $107,923 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income taxes $143,040 $154,336 $104,987 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Noncash investing and financing activities: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Change in unrealized appreciation (depreciation) of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decommissioning trust assets ($1,506) ($37) $3,205 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page\par\pard\plain\f0\fs16\par\pard\plain\cf1\f50\fs16\ql SYSTEM ENERGY RESOURCES, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql BALANCE SHEETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ASSETS \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql CURRENT ASSETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and cash equivalents: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash $44 $136 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Temporary cash investments - at cost, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql which approximates market 202,174 35,016 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total cash and cash equivalents 202,218 35,152 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Accounts receivable: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Associated companies 212,551 301,287 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 2,194 670 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total receivables 214,745 301,957 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Materials and supplies - at average cost 52,235 61,264 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deferred nuclear refueling outage costs 6,577 18,665 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Prepayments and other 2,639 2,251 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 478,414 419,289 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql OTHER PROPERTY AND INVESTMENTS \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Decommissioning trust funds 157,572 135,384 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql UTILITY PLANT \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Electric 3,093,033 3,060,324 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Property under capital lease 449,851 434,993 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Construction work in progress 24,029 58,510 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Nuclear fuel under capital lease 49,256 78,020 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL UTILITY PLANT 3,616,169 3,631,847 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Less - accumulated depreciation and amortization 1,407,885 1,312,559 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql UTILITY PLANT - NET 2,208,284 2,319,288 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql DEFERRED DEBITS AND OTHER ASSETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Regulatory assets: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SFAS 109 regulatory asset - net 195,634 242,834 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Unamortized loss on reacquired debt 51,957 56,474 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other regulatory assets 174,517 185,910 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other 8,172 9,869 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL 430,280 495,087 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql TOTAL ASSETS $3,274,550 $3,369,048 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ========== ========== \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql SYSTEM ENERGY RESOURCES, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql BALANCE SHEETS \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql LIABILITIES AND SHAREHOLDER'S EQUITY \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql CURRENT LIABILITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Currently maturing long-term debt $151,800 $77,947 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accounts payable: \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Associated companies 2,722 15,237 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 23,585 18,470 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Taxes accrued 68,530 55,383 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accumulated deferred income taxes 1,648 7,162 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Interest accrued 44,007 40,000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Obligations under capital leases 32,119 38,421 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 1,674 1,651 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 326,085 254,271 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql DEFERRED CREDITS AND OTHER LIABILITIES \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accumulated deferred income taxes 391,505 481,945 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accumulated deferred investment tax credits 89,516 93,219 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Obligations under capital leases 17,137 39,599 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql FERC settlement - refund obligation 30,745 37,337 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other regulatory liabilities 103,634 73,313 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Decommissioning 153,197 129,503 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Regulatory reserves 322,368 267,771 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Accumulated provisions 689 2,016 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Other 15,394 16,014 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 1,124,185 1,140,717 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Long-term debt 930,854 1,082,579 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql SHAREHOLDER'S EQUITY \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Common stock, no par value, authorized 1,000,000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql shares; issued and outstanding 789,350 shares in 2000 and \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 1999 789,350 789,350 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Retained earnings 104,076 102,131 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL 893,426 891,481 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ---------- ---------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Commitments and Contingencies (Notes 2, 9, and 10) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $3,274,550 $3,369,048 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql ========== ========== \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql See Notes to Financial Statements. \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SYSTEM ENERGY RESOURCES, INC. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql STATEMENTS OF RETAINED EARNINGS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql For the Years Ended December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retained Earnings, January 1 $102,131 $94,759 $60,583 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Add: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income 93,745 82,372 106,476 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deduct: \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Dividends declared 91,800 75,000 72,300 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- ------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retained Earnings, December 31 (Note 8) $104,076 $102,131 $94,759 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ======== ======== ======= \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See Notes to Financial Statements. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql SYSTEM ENERGY RESOURCES, INC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 1999 1998 1997 1996 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (Dollars In Thousands) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Operating revenues $ 656,749 $ 620,032 $ 602,373 $ 633,698 $ 623,620 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Net income $ 93,745 $ 82,372 $ 106,476 $ 102,295 $ 98,668 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total assets $3,274,550 $3,369,048 $3,431,205 $3,432,031 $3,461,293 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Long-term obligations (1) $ 947,991 $1,122,178 $1,182,616 $1,364,161 $1,474,427 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Electric energy sales (GWH) 9,621 7,567 8,259 9,735 8,302 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (1) Includes long-term debt (excluding current maturities) and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql noncurrent capital lease obligations. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \page \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ENTERGY CORPORATION AND SUBSIDIARIES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql NOTES TO FINANCIAL STATEMENTS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Entergy Corporation, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, Entergy New Orleans, and System Energy) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The accompanying consolidated financial statements include the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accounts of Entergy Corporation and its direct and indirect subsidiaries, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql including the domestic utility companies and System Energy, whose separate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial statements are included in this document. The financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements presented herein result from these companies having registered \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql securities with the SEC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql As required by generally accepted accounting principles, all \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql significant intercompany transactions have been eliminated in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql consolidated financial statements. The domestic utility companies and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy maintain accounts in accordance with FERC and other \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulatory guidelines. Certain previously reported amounts have been \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reclassified to conform to current classifications, with no effect on net \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql income or shareholders' equity. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation sold its investments in Entergy London and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql CitiPower in December 1998. Accordingly, the consolidated statements of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql income and cash flows for 1998 include amounts for Entergy London and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql CitiPower through the dates of their respective sales. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Use of Estimates in the Preparation of Financial Statements \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The preparation of Entergy Corporation's and its subsidiaries' \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial statements, in conformity with generally accepted accounting \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql principles, requires management to make estimates and assumptions that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql affect the reported amounts of assets and liabilities and disclosure of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql contingent assets and liabilities and the reported amounts of revenues and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expenses. Adjustments to the reported amounts of assets and liabilities \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql may be necessary in the future to the extent that future estimates or \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql actual results are different from the estimates used. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Revenues and Fuel Costs \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas, Entergy Louisiana, and Entergy Mississippi generate, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmit, and distribute electricity primarily to retail customers in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas, Louisiana, and Mississippi, respectively. Entergy Gulf States \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generates, transmits, and distributes electricity primarily to retail \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql customers in Texas and Louisiana. Entergy Gulf States also distributes gas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to retail customers in and around Baton Rouge, Louisiana. Entergy New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans sells both electricity and gas to retail customers in the City of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans, except for Algiers, where Entergy Louisiana is the electricity \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql supplier. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy's operating revenues are intended to recover operating \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expenses and capital costs attributable to Grand Gulf 1 from Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Capital costs are computed by allowing a return on System Energy's common \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql equity funds allocable to its net investment in Grand Gulf 1, plus System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Energy's effective interest cost for its debt allocable to its investment \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in Grand Gulf 1. System Energy's proposed rate increase is discussed in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Note 2 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy recognizes revenue from electricity and gas sales when the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql consumers are billed. The domestic utility companies also accrue estimated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql revenues for energy delivered since the latest billings on a monthly basis. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The monthly estimated unbilled revenue amounts are recorded as revenue and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql a receivable and are reversed the following month. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The domestic utility companies' rate schedules include either fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adjustment clauses or fixed fuel factors, both of which allow either \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql current recovery or deferral of fuel costs until such costs are reflected \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in the related revenues. Because the fuel adjustment clause mechanism \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql allows monthly adjustments to recover fuel costs, Entergy Louisiana, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans, and the Louisiana portion of Entergy Gulf States \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql include fuel cost recovery in their unbilled revenue calculations. Fixed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel factors remain in effect until changed as part of a general rate case, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel reconciliation, or fixed fuel factor filing. In the case of Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas, the Texas portion of Entergy Gulf States, and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi, their fuel under-recoveries are treated as regulatory \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql investments in the cash flow statements because those companies are allowed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by their regulatory jurisdictions to recover the fuel cost regulatory asset \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql over longer than a twelve month period, and the companies will earn a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql return on the under-recovered balances. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Utility Plant \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Utility plant is stated at original cost. The original cost of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility plant retired or removed, plus the applicable removal costs, less \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql salvage, is charged to accumulated depreciation. Maintenance, repairs, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql minor replacement costs are charged to operating expenses. Substantially \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql all of the utility plant is subject to liens from mortgage bond indentures. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql With regard to nuclear refueling outage costs, Entergy records the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs in accordance with regulatory treatment and the matching principle. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql These refueling outage expenses are incurred to prepare the units to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operate for the next 18 months without having to be taken off line. Except \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with respect to the River Bend plant, the costs are deferred during the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql outage and amortized over the period to the next outage. For the River \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Bend plant, the costs are accrued in advance and included in the cost of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql service used to establish retail rates, and are then amortized over the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql period between outages, which is in accordance with their regulatory \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql treatment. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Utility plant includes the portions of Grand Gulf 1 and Waterford 3 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that have been sold and leased back. For financial reporting purposes, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql these sale and leaseback arrangements are reflected as financing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transactions. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net utility plant by company and functional category, as of December \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 31, 2000, is shown below (in millions): \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Entergy Entergy Entergy Entergy Entergy System \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Entergy Arkansas Gulf States Louisiana Mississippi New Orleans Energy \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Production \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Nuclear $7,126 $1,092 $1,817 $1,779 $- $- $2,103 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Other 2,021 329 595 195 204 12 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Transmission 1,693 504 517 323 316 24 9 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Distribution 3,532 1,074 963 796 517 182 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Other 725 149 164 172 115 27 23 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Plant acquisition adjustment - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Entergy Gulf States 391 - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Other 91 - 23 - - 68 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Construction work in progress 937 87 145 85 44 36 24 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Nuclear fuel 435 114 57 64 - - 49 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql (leased and owned) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Accumulated provision for \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql decommissioning (1) (454) (283) (73) (98) - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ------------------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Utility plant - net $16,497 $3,066 $4,208 $3,316 $1,196 $349 $2,208 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ========================================================================= \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (1) The decommissioning liabilities related to Grand Gulf 1, Pilgrim, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the 30% of River Bend previously owned by Cajun are recorded in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql applicable Balance Sheets in "Deferred Credits and Other Liabilities - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Decommissioning." \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation is computed on the straight-line basis at rates based on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the estimated service lives and costs of removal of the various classes of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql property. Depreciation rates on average depreciable property are shown \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql below: \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Entergy Entergy Entergy Entergy Entergy System \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Entergy Arkansas Gulf States Louisiana Mississippi New Orleans Energy \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 2000 2.9% 3.2% 2.4% 3.0% 2.5% 3.1% 3.3% \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 1999 2.9% 3.2% 2.4% 2.9% 2.4% 3.0% 3.3% \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql 1998 3.0% 3.3% 2.6% 3.0% 2.5% 3.1% 3.3% \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql AFUDC represents the approximate net composite interest cost of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql borrowed funds and a reasonable return on the equity funds used for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql construction. Although AFUDC increases both utility plant and earnings, it \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql is realized in cash through depreciation provisions included in rates. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Jointly-Owned Generating Stations \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Certain Entergy subsidiaries jointly own electric generating \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql facilities with third parties. The investments and expenses associated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with these generating stations are recorded by the Entergy subsidiaries to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the extent of their respective undivided ownership interests. As of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, 2000, the subsidiaries' investment and accumulated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql depreciation in each of these generating stations were as follows: \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Total \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Megawatt Accumulated \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Generating Stations Fuel-Type Capability Ownership Investment Depreciation \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql (In Millions) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Entergy Arkansas \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Independence Unit 1 Coal 836 31.50% $117 $58 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Common Facilities Coal 15.75% 30 14 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql White Bluff Units 1 and 2 Coal 1,659 57.00% 405 219 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Entergy Gulf States \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Roy S. Nelson Unit 6 Coal 550 70.00% 403 208 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Big Cajun 2 Unit 3 Coal 575 42.00% 228 111 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Entergy Mississippi - \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Independence Units 1 and 2 and Coal 1,678 25.00% 227 99 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Common Facilities \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql System Energy - \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Grand Gulf Unit 1 Nuclear 1,210 90.00%(1) 3,531 1,408 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Entergy Power - \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Independence Unit 2 Coal 842 14.37% 76 31 \par\pard\plain\fs16\pard\plain\cf1\f50\fs18\ql Common Facilities Coal 7.18% 5 3 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (1)Includes an 11.5% leasehold interest held by System Energy. System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Energy's Grand Gulf 1 lease obligations are discussed in Note 10 to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Project Development Costs \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy capitalizes costs incurred in developing projects after \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql achieving certain milestones that indicate that completion of the project \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql is probable. These costs include salaries, incremental indirect costs and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amounts paid to outside parties for such expenses as legal, engineering, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accounting, and other incremental direct costs. Capitalized project \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql development costs are transferred to construction in progress during the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql construction phase and to electric plant after commencement of operations. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Capitalized costs are amortized over the life of operational projects or \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql charged to expense if management determines that the costs are not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recoverable through operations of the project. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income Taxes \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Corporation and its subsidiaries file a U.S. consolidated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql federal income tax return. Income taxes are allocated to the subsidiaries \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in proportion to their contribution to consolidated taxable income. SEC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulations require that no Entergy subsidiary pay more taxes than it would \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql have paid if a separate income tax return had been filed. In accordance \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with SFAS 109, "Accounting for Income Taxes," deferred income taxes are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recorded for all temporary differences between the book and tax basis of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql assets and liabilities, and for certain credits available for carryforward. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Deferred tax assets are reduced by a valuation allowance when, in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql opinion of management, it is more likely than not that some portion of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deferred tax assets will not be realized. Deferred tax assets and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql liabilities are adjusted for the effects of changes in tax laws and rates \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql on the date of enactment. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Investment tax credits are deferred and amortized based upon the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql average useful life of the related property, in accordance with ratemaking \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql treatment. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Reacquired Debt \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The premiums and costs associated with reacquired debt of the domestic \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility companies and System Energy (except that portion allocable to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deregulated operations of Entergy Gulf States) are being amortized over the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql life of the related new issuances, in accordance with ratemaking treatment. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cash and Cash Equivalents \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy considers all unrestricted highly liquid debt instruments \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchased with an original maturity of three months or less to be cash \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql equivalents. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Investments \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy applies the provisions of SFAS 115, "Accounting for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Investments for Certain Debt and Equity Securities," in accounting for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql investments in decommissioning trust funds. As a result, Entergy has \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recorded on the consolidated balance sheet $128 million of additional value \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in its decommissioning trust funds. This increase represents the amount by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql which the fair value of the securities held in such funds exceeds the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amounts deposited plus the earnings on the deposits. In accordance with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the regulatory treatment for decommissioning trust funds, the domestic \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility companies and System Energy have recorded an offsetting amount in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql unrealized gains on investment securities as a regulatory liability in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql other deferred credits. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Decommissioning trust funds for Pilgrim do not receive regulatory \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql treatment. Accordingly, unrealized gains recorded on the assets in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Pilgrim's trust funds are recognized as a separate component of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql shareholders' equity because these assets are classified as available for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql sale. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Foreign Currency Translation \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql All assets and liabilities of Entergy's foreign subsidiaries are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql translated into U.S. dollars at the exchange rate in effect at the end of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the period. Revenues and expenses are translated at average exchange rates \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql prevailing during the period. The resulting translation adjustments are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reflected in a separate component of shareholders' equity. Current \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql exchange rates are used for U.S. dollar disclosures of future obligations \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql denominated in foreign currencies. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Earnings per Share \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The average number of common shares outstanding for the presentation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of diluted earnings per share was greater by approximately 1,960,858 shares \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in 2000, 199,000 shares in 1999, and 176,000 shares in 1998, than the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql number of such shares for the presentation of basic earnings per share due \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to Entergy's stock option and other stock compensation plans discussed more \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql thoroughly in Note 5 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Options to purchase approximately 5,205,000 and 149,000 shares of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql common stock at various prices were outstanding at the end of 1999 and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1998, respectively, but were not included in the computation of diluted \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql earnings per share because the exercise prices were greater than the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql average market price of the common shares at the end of each of the years \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql presented. At the end of 2000, all outstanding options, totaling \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 11,468,316, were included in the computation of diluted earnings per share \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql as a result of the average market price of the common shares being greater \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql than the exercise prices. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Application of SFAS 71 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The domestic utility companies and System Energy currently account for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the effects of regulation pursuant to SFAS 71, "Accounting for the Effects \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Certain Types of Regulation." This statement applies to the financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statements of a rate-regulated enterprise that meet three criteria. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql enterprise must have rates that (i) are approved by the regulator; (ii) are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cost-based; and (iii) can be charged to and collected from customers. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql These criteria may also be applied to separable portions of a utility's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql business, such as the generation or transmission functions, or to specific \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql classes of customers. If an enterprise meets these criteria, it may \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql capitalize costs that would otherwise be charged to expense if the rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql actions of its regulator make it probable that those costs will be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovered in future revenue. Such capitalized costs are reflected as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulatory assets in the accompanying financial statements. A significant \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql majority of Entergy's regulatory assets, net of related regulatory and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deferred tax liabilities, earn a return on investment during their recovery \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql periods. SFAS 71 requires that rate-regulated enterprises assess the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql probability of recovering their regulatory assets at each balance sheet \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql date. When an enterprise concludes that recovery of a regulatory asset is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql no longer probable, the regulatory asset must be removed from the entity's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql balance sheet. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SFAS 101, "Accounting for the Discontinuation of Application of FASB \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Statement No. 71," specifies how an enterprise that ceases to meet the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql criteria for application of SFAS 71 for all or part of its operations \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql should report that event in its financial statements. In general, SFAS 101 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql requires that the enterprise report the discontinuation of the application \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of SFAS 71 by eliminating from its balance sheet all regulatory assets and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql liabilities related to the applicable segment. Additionally, if it is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql determined that a regulated enterprise is no longer recovering all of its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs and therefore no longer qualifies for SFAS 71 accounting, it is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql possible that an impairment may exist that could require further write-offs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of plant assets. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql EITF 97-4: "Deregulation of the Pricing of Electricity - Issues \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Related to the Application of FASB Statements No. 71 and 101" specifies \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that SFAS 71 should be discontinued at a date no later than when the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql effects of a transition to competition plan for all or a portion of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql entity subject to such plan are reasonably determinable. Additionally, EITF \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 97-4 promulgates that regulatory assets to be recovered through cash flows \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql derived from another portion of the entity that continues to apply SFAS 71 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql should not be written off; rather, they should be considered regulatory \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql assets of the segment that will continue to apply SFAS 71. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql As described in "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql SIGNIFICANT FACTORS AND KNOWN TRENDS," management believes that definitive \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql outcomes have not yet been determined regarding transition to competition \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in any of Entergy's jurisdictions. Therefore, the regulated operations of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the domestic utility companies and System Energy continue to apply SFAS 71. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas and Texas have enacted retail open access laws, but Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql believes that significant issues remain to be addressed by Arkansas and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Texas regulators, and the enacted laws do not provide sufficient detail to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reasonably determine the impact on Entergy Arkansas' and Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States' regulated operations. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Transition to Competition Liabilities \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In conjunction with the transition to competition of the electric \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility industry in certain jurisdictions in which the domestic utility \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies operate, regulatory mechanisms have been established to mitigate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql potential stranded costs. These mechanisms include the transition cost \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql account at Entergy Arkansas, which is discussed further in Note 2 to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql financial statements. Also included is a provision in the Texas transition \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql legislation that allows depreciation on transmission and distribution \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql assets to be directed toward generation assets. The liabilities recorded \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql as a result of these mechanisms are classified as "transition to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competition" deferred credits. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Domestic Operating Company Deregulated Operations \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States does not apply regulatory accounting principles to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql its wholesale jurisdiction, steam department, Louisiana retail deregulated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql portion of River Bend, and the 30% interest in River Bend formerly owned by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Cajun. The Louisiana retail deregulated portion of River Bend is operated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql under a deregulated asset plan representing a portion (approximately 24%) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of River Bend plant costs, generation, revenues, and expenses established \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql under a 1992 LPSC order. The plan allows Entergy Gulf States to sell the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql electricity from the deregulated assets to Louisiana retail customers at \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 4.6 cents per KWH or off-system at higher prices, with certain provisions \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for sharing such incremental revenue above 4.6 cents per KWH between \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ratepayers and shareholders. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The results of these deregulated operations before interest charges for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the years ended December 31, 2000, 1999, and 1998 are as follows (in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql thousands): \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000 1999 1998 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operating revenues $200,023 $166,509 $178,303 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Operating expenses \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel, operating, and maintenance 141,822 126,917 137,579 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Depreciation 36,158 35,141 39,497 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total operating expense 177,980 162,058 177,076 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income tax expense 8,278 628 1,154 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql -------- -------- -------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Net income from deregulated utility operations $13,765 $3,823 $73 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ======== ======== ======== \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The net investment associated with these deregulated operations as of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, 2000 and 1999 was approximately $822 million and $835 million, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql respectively. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Impairment of Long-Lived Assets \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy periodically reviews long-lived assets whenever events or \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql changes in circumstances indicate that recoverability of these assets is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql uncertain. Generally, the determination of recoverability is based on the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql net cash flows expected to result from such operations and assets. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Projected net cash flows depend on the future operating costs associated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with the assets, the efficiency and availability of the assets and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generating units, and the future market and price for energy over the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql remaining life of the assets. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Assets regulated under traditional cost-of-service ratemaking, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql thereby subject to SFAS 71 accounting, are generally not subject to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql impairment because this form of regulation assures that all allowed costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql are subject to recovery. However, certain deregulated assets and other \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operations of the domestic utility companies totaling approximately $1.5 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql billion (pre-tax) could be affected in the future. Those assets include \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas' and Entergy Louisiana's retained shares of Grand Gulf 1, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States' Louisiana deregulated asset plan, the Texas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql jurisdictional abeyed portion of the River Bend plant and the portion of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql River Bend transferred from Cajun, and wholesale operations. Additionally, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql as noted above, the discontinuation of SFAS 71 regulatory accounting \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql principles would require that Entergy review the affected assets for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql impairment. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Derivative Financial Instruments and Commodity Derivatives \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql As a part of its overall risk management strategy, Entergy uses a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql variety of derivative financial instruments and commodity derivatives, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql including interest rate swaps and natural gas and electricity futures, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql forwards, and options. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy accounts for derivative financial instruments used to mitigate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql interest rate risk in accordance with hedge accounting. Gains or losses \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql from rate swaps used for such purposes that are sold or terminated are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deferred and amortized over the remaining life of the debt instrument being \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql hedged by the interest rate swap. If the debt instrument being hedged by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the interest rate swaps is extinguished, any gain or loss attributable to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the swap would be recognized in the period of the transaction. Additional \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql information concerning Entergy's interest rate swaps outstanding as of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, 2000 is included in Note 7 to the financial statements. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's power marketing and trading business engages in price risk \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql management activities for trading purposes. To conduct these activities, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the business uses futures, forwards, swaps, and options, and uses the mark- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to-market method of accounting. Under the mark-to-market method of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accounting, forwards, futures, swaps, options, and other financial \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql instruments with third parties are reflected at market value in the balance \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql sheets. Changes in the assets and liabilities from these instruments \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (resulting primarily from newly originated transactions and the impact of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql price movements) are recognized currently in the statements of income. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql market prices used to value these transactions reflect management's best \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql estimate considering various factors including closing exchange and over- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the-counter quotations, time value, and volatility factors underlying the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commitments. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Accounting Pronouncements \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In June 1998, the FASB issued SFAS 133, "Accounting for Derivative \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Instruments and Hedging Activities," which was implemented effective \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql January 1, 2001. This statement requires that all derivatives be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recognized in the balance sheet, either as assets or liabilities, measured \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql at fair value. The changes in the fair value of derivatives are recorded \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql each period in current earnings or other comprehensive income, depending on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql whether a derivative is designated as part of a hedge transaction and, if \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql it is, the type of hedge transaction. For fair-value hedge transactions in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql which Entergy is hedging changes in an asset's, liability's, or firm \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commitment's fair value, changes in the fair value of the derivative \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql instrument will generally be offset in the income statement by changes in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the hedged item's fair value. For cash-flow hedge transactions in which \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy is hedging the variability of cash flows related to a variable-rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql asset, liability, or a forecasted transaction, changes in the fair value of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the derivative instrument will be reported in other comprehensive income. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The gains and losses on the derivative instrument that are reported in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql other comprehensive income will be reclassified as earnings in the periods \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in which earnings are impacted by the variability of the cash flows of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql hedged item. The ineffective portion of all hedges will be recognized in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql current-period earnings. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy utilizes derivative financial instruments primarily for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql following purposes: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o trading activity in its power marketing and trading business; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o to ensure adequate power supplies and to mitigate certain risks in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility business; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o to hedge cash flows for various transactions in its competitive \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql businesses. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The implementation of SFAS 133 did not materially impact the power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql marketing and trading business, as its derivative portfolio is already \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql marked-to-market under the provisions of EITF 98-10, "Measuring the Value \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of Energy-Related Contracts". Effective January 1, 2001, Entergy recorded \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql a net-of-tax cumulative-effect-type adjustment of approximately $18.0 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million reducing accumulated other comprehensive income to recognize at fair \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql value all derivative instruments that are designated as cash-flow \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql hedging instruments, primarily for interest rate swaps and foreign currency \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql forward contracts related to Entergy's competitive businesses. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The FASB's Derivatives Implementation Group (DIG) is considering a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql number of issues affecting the power industry. Entergy's interpretation of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql these issues in its initial implementation of SFAS 133 is based on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql management's application of existing accounting literature. To the extent \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that the DIG ultimately interprets these issues differently than Entergy, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy's financial statements could be materially affected, although the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amount of the possible effect cannot be quantified at this time. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql NOTE 2. RATE AND REGULATORY MATTERS \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Electric Industry Restructuring \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (Entergy Corporation and Entergy Arkansas) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In April 1999, the Arkansas legislature enacted a law providing for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competition in the electric utility industry through retail open access as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of January 1, 2002. With retail open access, generation operations would \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql become a competitive business, but transmission and distribution operations \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql will continue to be regulated either by federal or state regulatory \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commissions. In November 2000, the APSC issued a report to the General \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Assembly on the status of deregulation implementation and recommended that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the deregulation statute remain as passed in 1999 except that the target \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql date for retail open access be delayed until no sooner than October 1, 2003 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and no later than October 1, 2005. The investor-owned utilities in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas signed a settlement agreement that supported the recommendation. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql During the 2001 legislative session, the General Assembly passed an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amendment to the deregulation statute to adopt the APSC recommendation to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amend the target date for retail open access. The amendment was signed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql into law by the governor in February 2001. Besides delaying the target \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql date, the amendment includes two new criteria that will allow the APSC to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql delay the retail open access date beyond the October 1, 2003 target. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql additional criteria that could cause further delay include: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o most customers would not have a reasonable opportunity to realize net \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql benefits, specifically including relative price benefits for residential \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and small business customers; or \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o demonstrably effective market structures are not in place, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql particularly a regional transmission organization or insufficient \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generation and transmission capacity. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other provisions of the currently enacted law: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o require utilities to separate (unbundle) their costs into generation, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmission, distribution, and customer service functions; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o require customer service functions to be further unbundled into \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competitive and regulated services based on the APSC's determination that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql billing services be competitive as of retail open access; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o require operation of transmission facilities by an organization \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql independent from the generation, distribution, and retail operations; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o provide for the determination of and mitigation measures for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generation market power,which could require generation asset divestitures \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql or other mitigation measures; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o allow for recovery of stranded and transition costs if the costs are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approved by the APSC; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o allow for the securitization of approved stranded costs; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o freeze residential and small business customer rates for three years \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by utilities that will recover stranded costs and one year for other \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utilities. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas filed separate generation, transmission, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql distribution, and customer service rates with the APSC in December 1999 and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql also filed notice of its intent to recover stranded costs. Should \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utilities that have filed notice of stranded cost recovery determine that, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql due to the delay in retail open access, stranded cost recovery is not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql required, notice of intent to withdraw from seeking stranded cost recovery \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql must be filed by December 31, 2001. Entergy Arkansas' unbundled rates were \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql based on the cost-of-service study that formed the basis of the rates \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql included in the 1997 settlement agreement. In October 2000, a settlement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql agreement was filed settling all outstanding issues except one rate design \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql issue. In December 2000, the APSC approved the unbundled rates as filed, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approved the October 2000 settlement agreement, and ordered compliance \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql tariffs be filed within 60 days. Bundled rates will continue to be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql effective until six months prior to retail open access. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The APSC and various participants in the industry, including Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas, are involved in the ongoing process of implementing the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql legislation through various rulemaking and other proceedings. Some \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rulemakings were suspended in late 2000 in anticipation of a delay in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql target date for retail open access. In compliance with the provisions of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the deregulation law and as a result of rulemakings concluded in 2000, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas has: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o filed a functional, but not corporate, unbundling plan with the APSC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in August 2000. The functional unbundling plan initially establishes \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql separate business units for distribution, generation, and a new retail \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql energy service provider. The plan contemplates the transfer of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmission assets to the Transco discussed herein. The functional \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql unbundling plan is tentative because the regulatory requirements to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql implement the retail open access law have not been finalized, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql changes to the plan are possible; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o filed a compliance plan in October 2000 detailing the specific \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql procedures to ensure that the affiliate rules are implemented; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o filed unbundled compliance tariffs in February 2001; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o filed a market power study in October 2000 in accordance with the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql guidelines adopted by the APSC. The study included both wholesale \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generation and retail markets and examined vertical and horizontal market \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power issues. Due to the delay in retail open access, Entergy Arkansas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql will file an updated study in 2001 reflecting any changes in generation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql supply in the study region; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o agreed to file the stranded cost proceedings following the market \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power proceeding; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o participated in various rulemakings related to standard service \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql package offerings, the declaration of billing services as a competitive \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql service, electronic data exchange, consumer education, and affiliate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rules. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In June 2000, the APSC declared that billing would become a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competitive service at the beginning of retail open access. In December \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, the APSC issued an order requiring utilities to file further customer \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql service costs from the competitive services costs. In May 2001, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas will file further unbundled customer service rates to separate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql those costs associated with those billings services that were declared \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competitive as of retail open access from those customer services still \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regulated by the APSC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In December 2000, Entergy Arkansas filed an application for approval \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to transfer Entergy Arkansas' transmission assets to an independent company \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (Transco). This transfer of transmission assets is to comply with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql establishing independent transmission operations in accordance with federal \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and state deregulation requirements. Entergy's Transco proposal is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql discussed in "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - SIGNIFICANT \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FACTORS AND KNOWN TRENDS - Open Access Transmission and Entergy's Transco \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Proposal". \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Texas \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (Entergy Corporation and Entergy Gulf States) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In June 1999, the Texas legislature enacted a law providing for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competition in the electric utility industry through retail open access. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The law provides for retail open access by most investor-owned electric \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utilities, including Entergy Gulf States, on January 1, 2002. With retail \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql open access, generation and a new retail electric provider operation will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql be competitive businesses, but transmission and distribution operations \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql will continue to be regulated. The new retail electric provider will be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the primary point of contact with customers. The provisions of the new \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql law: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o require a rate freeze through December 31, 2001 with rates reduced by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 6% beyond that for residential and small commercial customers of most \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql incumbent utilities except Entergy Gulf States,whose rates are exempt \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql from the 6% reduction requirement. These rates to residential and small \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commercial customers are known as the "Price to Beat", and they may be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adjusted periodically after January 1, 2002 for fuel and purchased power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs according to PUCT rules; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o require utilities to charge the Price to Beat rates through 2004, or \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql until 40% of customers in the jurisdiction have chosen an alternative \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql supplier, whichever comes first. However, the Price to Beat rates must \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql continue to be made available through 2006; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o require utilities to submit a plan to separate (unbundle) their \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generation, transmission and distribution, and retail electric provider \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql functions, which Entergy Gulf States filed in January 2000 as discussed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql below; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o require utilities to comply with a code of conduct to ensure that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utilities do not allow affiliates to have a business advantage over \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competitors; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o require operation in a non-discriminatory manner of transmission and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql distribution facilities by an organization independent from the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generation and retail operations by the time competition is implemented; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o allow for recovery of stranded costs incurred in purchasing power and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql providing electric generation service if the costs are approved by the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PUCT; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o allow securitization of regulatory assets and PUCT-approved stranded \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o provide for the determination of and mitigation measures for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generation market power; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o required utilities to file separated cost data and proposed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmission, distribution,and competition transition tariffs by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql April 1, 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States filed its business separation plan with the PUCT \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in January 2000 to separate its functions, and amended that plan in June \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and December 2000. The plan provides that, by January 2002, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States will be divided into a Texas distribution company, a Texas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transmission company, a Texas generation company, at least two Texas retail \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql electricity providers, and a Louisiana company that will encompass \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql distribution, generation, transmission, and retail operations. In July \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, the PUCT issued an interim order approving the amended business \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql separation plan. The plan provides that the Louisiana company would retain \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the liability for all debt obligations of Entergy Gulf States and that the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql property of the Texas companies would be released from the lien of Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States' mortgage. Except for the Texas retail electric providers, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql each of the Texas companies would assume a portion of Entergy Gulf States' \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql debt obligations, which assumptions would not act to release the Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql company's obligations. Except for the Texas retail electric providers, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql each of the Texas companies would also grant a lien on its properties in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql favor of the Louisiana company to secure its obligations to the Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql company in respect of the assumed obligations. In addition, under the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql plan, Entergy Gulf States will refinance or retire the Texas companies' \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql portion of existing debt by the end of 2004. Regulatory approvals from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FERC, the SEC, and the LPSC, and final approval from the PUCT will be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql required before the business separation plan can be implemented. Remaining \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql business separation issues in Texas subsequent to the July 2000 interim \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql order will be addressed in the cost unbundling proceeding before the PUCT. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The LPSC has opened a docket to identify the changes in corporate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql structure of Entergy Gulf States, and their potential impact on Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql retail ratepayers, resulting from restructuring in Texas and Arkansas. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States filed testimony in that proceeding in August 2000. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LPSC staff filed testimony in that proceeding in October 2000 criticizing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States' proposal, particularly the part related to the Texas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql portion of generation assets being transferred to an unregulated entity. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States filed rebuttal testimony in December 2000. A \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql procedural schedule has not been set. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Beginning January 1, 2002, the market power measures in the open \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql access law will prohibit Entergy Gulf States from owning and controlling \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql more than 20% of the installed generation capacity located in, or capable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of delivering electricity to, a "power region", which is defined as a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql distinct region of NERC. In seeking PUCT approval of the Merger, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and FPL Group are required to demonstrate that the merged company will not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql exceed this threshold. However, all the implications of this limit are \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql uncertain for Entergy Gulf States and Entergy. It is possible that Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States could decide to divest some of its generation assets or seek to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reduce transmission constraints if Entergy Gulf States is found to have \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql generation market power in excess of this limit. The legislation also \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql requires affected utilities to sell at auction entitlements to at least 15% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of their installed generation capacity in Texas at least 60 days before \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql January 1, 2002. The obligation to auction capacity entitlements continues \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for up to 60 months after January 1, 2002, or until 40% of current \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql customers have chosen an alternative supplier, whichever comes first. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The PUCT and various participants in the industry are currently in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql process of implementing the legislation through various rulemaking and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql other proceedings. The Provider of Last Resort (POLR) rule was approved by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the PUCT in October 2000, requiring that such a provider exist in every \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql area of the state and setting up the process by which such a provider will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql be selected and its services priced. The PUCT received bids from retail \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql electric providers seeking to become the POLR in each area in January 2001. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The PUCT has stated its preference that the POLR not be the retail electric \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql provider that is affiliated with the incumbent utility in the area. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql However, depending on the outcome of the bidding process, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States' affiliate retail electric provider may be required to provide POLR \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql service in Entergy Gulf States' service territory. This may have a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql material financial impact on the Entergy Gulf States retail electric \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql provider depending on the terms and prices eventually approved by the PUCT \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for POLR service. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql On March 31, 2000, pursuant to the Texas restructuring legislation, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States filed cost data with the PUCT for its unbundled \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql business functions and proposed tariffs for its unbundled distribution \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql utility. In the filing, Entergy Gulf States is seeking approval for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovery of the following, among other things: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the unbundled distribution utility's cost of service; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a ten-year nonbypassable charge to recover estimated stranded costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and a nonbypassable charge to recover nuclear decommissioning costs. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Also included in the proceeding is consideration of the treatment of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 30% share of River Bend acquired from Cajun, which Entergy Gulf States \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql treats as an asset not subject to regulation by the PUCT. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql On March 6, 2001, Entergy Gulf States filed with the PUCT a non- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql unanimous settlement agreement in the unbundled cost proceeding that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql establishes the distribution revenue requirement. The settlement agreement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql is between Entergy Gulf States, the PUCT Staff, and other parties. Pursuant \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to a generic rule prescribed by the PUCT, Entergy Gulf States' allowed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql return on equity will be 11.25%. The generic capital structure prescribed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by the PUCT is 60% debt and 40% equity. Also in the settlement agreement, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the parties agree that Entergy Gulf States' stranded costs and benefits \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql are $0, and no charge to recover stranded costs will be implemented. A \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rider to recover nuclear decommissioning costs will be implemented. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Hearings before the PUCT on approval of the settlement are scheduled to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql begin in April 2001. Management cannot predict the timing or outcome of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql this proceeding. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (Entergy Corporation, Entergy Gulf States, and Entergy Louisiana) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In March 1999, the LPSC deferred making a decision on whether \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql competition in the electric industry is in the public interest. However, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the LPSC staff, outside consultants, and counsel were directed to work \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql together to analyze and resolve issues related to competition and then \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recommend a plan for its implementation to be considered by the LPSC. In \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql January 2001, a draft response was circulated among interested parties. It \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql is expected that, after a comment period, a final staff response will be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql presented to the LPSC in April 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql See above under "Texas" for discussion of the LPSC proceeding \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql considering Entergy Gulf States' business separation plan. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (Entergy Corporation and Entergy Mississippi) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In May 2000, after two years of studies and hearings, the MPSC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql announced that it was suspending its docket studying the opening of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql state's retail electricity markets to competition. The MPSC based its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decision on its finding that competition could raise the electric rates \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql paid by residential and small commercial customers. The final decision \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql regarding the introduction of retail competition ultimately lies with the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi Legislature, which is holding its 2001 session from January \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql through March. Management cannot predict when, or if, Mississippi will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deregulate its retail electricity market, but does not expect it to occur \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql before 2003. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (Entergy Corporation and Entergy New Orleans) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans filed an electric transition to competition plan \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in September 1997. This plan is similar to plans that were filed by the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql other domestic utility companies. No procedural schedule has been \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql established for consideration of that plan by the Council. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In October 1998, the Council began proceedings to determine if natural \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql gas retail competition is in the public interest. Advisors to the Council \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql issued a final report that proposed various pilot programs and found that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql retail gas open access is not in the public interest at this time. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Council accepted an offer of settlement from Entergy New Orleans in this \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql matter that allows for a voluntary pilot program for a limited number of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql large industrial non-jurisdictional gas customers. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Retail Rate Proceedings \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Filings with the APSC (Entergy Corporation and Entergy Arkansas) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas is operating under the terms of a settlement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql agreement approved by the APSC in December 1997 that provides for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql following: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o accelerated payment of Entergy Arkansas' Grand Gulf purchased power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql obligation in an amount totaling $165.3 million over the period from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql January 1999 to June 2004; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o collecting earnings in excess of an 11% return on equity in a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql transition cost account to offset stranded costs when retail access is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql implemented; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a rate freeze until at least July 1, 2001; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o rate decreases totaling $200 million over the two-year period 1998- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999. The net income effect from the rate reductions was approximately \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $22 million. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In June 2000, Entergy Arkansas filed an application to continue the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql stranded cost mitigation efforts agreed upon in the settlement agreement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql including the funding of a transition cost account and the accelerated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amortization of the Grand Gulf obligation. In December 2000, the APSC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approved a settlement agreement that directed Entergy Arkansas to do the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql following: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o seek FERC approval for the cessation of the accelerated payment of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Grand Gulf purchased power obligation as of July 1, 2001,and approval was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql applied for in February 2001; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o continue the collection of excess earnings in a transition cost \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql account at least through 2002. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas' 2000 operating expenses reflect reserves of $4.4 million \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ($2.7 million net of taxes) to record the final determination of 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql excess earnings. Interest of $5.2 million ($3.2 million net of taxes) was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql also recorded in the transition cost account for 2000. As of December 31, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, the transition cost account balance was $119.6 million. Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas applied $17.5 million ($10.7 million net of tax) of 2000 excess \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql earnings recorded in the third quarter 2000 against 2000 ice storm damage \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expenses. For additional information on the December 2000 ice storms in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas, refer to "December 2000 Ice Storms" discussed below. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In March 2000, Entergy Arkansas filed its annually redetermined energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cost rate with the APSC in accordance with the energy cost recovery rider \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql formula and special circumstances agreement. The filing reflected that an \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increase was warranted to collect an under-recovery of energy costs for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999. The increased energy cost rate is effective April 2000 through March \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In October 2000, the APSC ordered Entergy Arkansas to cease collection \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of funds to decommission ANO 1 and 2 for the calendar year 2001. Based on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql anticipated approval of Entergy's application with the NRC to extend the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql license of ANO 1 by 20 years, the APSC concluded that the funds previously \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql collected will be sufficient to decommission the units. This decision will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql be reviewed annually and reflected in Entergy Arkansas' filing of its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql annual determination of the nuclear decommissioning rate rider. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Filings with the PUCT and Texas Cities \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Rate Proceedings (Entergy Corporation and Entergy Gulf States) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In June 1999, the PUCT approved a settlement agreement that Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States entered into in February 1999. The settlement agreement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql resolved Entergy Gulf States' 1996 and 1998 rate proceedings and all of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql settling parties' pending appeals in other matters, except for the appeal \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in the River Bend abeyed cost recovery proceeding discussed below. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Office of Public Utility Counsel, an intervenor in the proceeding, has \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql appealed certain aspects of this settlement to Travis County District \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Court. Entergy Gulf States cannot predict the impact of the appeal. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The settlement agreement provides for the following: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o an annual $4.2 million base rate reduction, effective March 1, 1999, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql which is in addition to the annual $69 million base rate reduction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (net of River Bend accounting order deferrals) in the PUCT's second order \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql on rehearing in October 1998; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a methodology for semi-annual revisions of the fixed fuel factor \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql through December 2001 based on the market price of natural gas; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a base rate freeze through June 1, 2000. The Texas restructuring law \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql extends the base rate freeze through December 2001; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o amortization of the remaining River Bend accounting order deferrals as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of January 1, 1999, over three years on a straight-line basis, and the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accounting order deferrals will not be recognized in any subsequent base \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rate case or stranded cost calculation; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the dismissal of all pending appeals of the settling parties relating \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to Entergy Gulf States' proceedings with the PUCT, except the River Bend \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql abeyed plant costs appeal discussed below; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o the potential recovery in the River Bend abeyed plant costs appeal is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql limited to $115 million net plant in service as of January 1, 2002, less \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql depreciation over the remaining life of the plant beginning January 1, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2002 through the date the plant costs are included in rate base, and any \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql such recovery will not be used to increase rates above the level agreed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to in the settlement agreement (see "Recovery of River Bend Costs" in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql this note for further discussion). \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql As a result of the settlement agreement, in June 1999, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o removed from its balance sheet a $207.3 million deferred asset and the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql associated provision recorded for unrecovered purchased power costs and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deferred revenue from NISCO, which had no net income impact on Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o removed the reserve recorded in December 1997 for River Bend plant \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs held in abeyance and reduced the plant asset, resulting in other \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql income of $4.8 million; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o removed the $93.9 million reserve recorded in 1998 for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amortization of River Bend accounting order deferrals to reflect the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql three-year amortization schedule detailed in the agreement. The income \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql impact of this removal was largely offset by an increase in the rate of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amortization of the accounting order deferrals. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In June 1999, the PUCT instituted a proceeding to consider the final \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adjustment of the rate refunds ordered as a result of Entergy Gulf States' \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql November 1996 rate case. These refunds were required to occur over the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fourteen-month period from August 1998 through September 1999. The PUCT \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql issued an order in July 1999 adopting a calculation methodology which \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql required Entergy Gulf States to refund an additional $25 million. This \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql refund was recorded as a reduction in operating revenues. The PUCT \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approved the final refund and concluded the proceeding in June 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Recovery of River Bend Costs (Entergy Corporation and Entergy Gulf States) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In March 1998, the PUCT disallowed recovery of $1.4 billion of company- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql wide abeyed River Bend plant costs which have been held in abeyance since \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1988. Entergy Gulf States appealed the PUCT's decision on this matter to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the Travis County District Court in Texas. In June 1999, subsequent to the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql settlement agreement discussed above, Entergy Gulf States removed the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reserve for River Bend plant costs held in abeyance and reduced the value \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the plant asset. The settlement agreement limits potential recovery of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the remaining plant asset, less depreciation, to $115 million, beginning \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql January 1, 2002 through the date the plant costs are included in rate base, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and any such recovery will not be used to increase rates above the level as \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql agreed to in the settlement agreement. The settlement agreement also \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql prohibits Entergy Gulf States from acting on its appeal until January 1, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2002. Based on advice of counsel, management believes that it is probable \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that the matter will be remanded again to the PUCT for a further ruling on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the prudence of the abeyed plant costs and it is reasonably possible that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql some portion of these costs will be added to the net book value of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql River Bend plant for regulatory purposes. However, no assurance can be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql given that additional reserves or write-offs will not be required in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql future. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PUCT Fuel Cost Review (Entergy Corporation and Entergy Gulf States) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In September 1998, Entergy Gulf States filed an application with the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PUCT for an increase in its fixed fuel factor and for a surcharge to Texas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql retail customers for the cumulative under-recovery of fuel and purchased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power costs. The PUCT issued an order in December 1998 approving the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql implementation of a revised fuel factor and fuel and purchased power \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql surcharge that would result in recovery of $112.1 million of under- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovered fuel costs, inclusive of interest, over a 24-month period. These \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increases were implemented in the first billing cycle in February 1999. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql North Star Steel Texas, Inc. has appealed the PUCT's order to the State \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql District Court in Travis County, Texas. Entergy Gulf States cannot predict \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the outcome of this appeal. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Based on the settlement agreement discussed above, Entergy Gulf States \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adopted a methodology for calculating its fixed fuel factor based on the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql market price of natural gas. This calculation and any necessary \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql adjustments began semi-annually as of March 1, 1999 and are scheduled to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql continue until December 2001, unless otherwise ordered by the PUCT. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql calculation for the factor that was implemented in September 2000 showed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that the fuel factor should be increased. This fuel factor increase was \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approved by the PUCT in August 2000. The amounts collected under Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States' fixed fuel factor are the subject of fuel reconciliation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql proceedings before the PUCT, including a fuel reconciliation case filed by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States in January 2001. In connection with the implementation \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of restructuring in Texas, Entergy Gulf States anticipates that it will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql file a final fuel reconciliation in March 2003 for the period ending \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States filed a fuel reconciliation case in July 1999 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reconciling approximately $731 million (after excluding approximately $14 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million related to Cajun issues to be handled in a subsequent proceeding) \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of fuel and purchased power costs incurred from July 1996 to February 1999. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In February 2000, Entergy Gulf States reached a settlement with all but one \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the parties to the proceeding. The settlement reduced Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States' requested surcharge in the reconciliation filing from $14.7 million \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to $2.2 million. In April 2000, the PUCT approved this settlement allowing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States to recover the $2.2 million surcharge beginning with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the April 2000 billing cycle and continuing until January 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In September 1999, Entergy Gulf States filed an application with the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql PUCT requesting an interim fuel surcharge to collect under-recovered fuel \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and purchased power expenses incurred from March 1999 through July 1999. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In December 1999, the PUCT approved the collection of $33.9 million over a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql five-month period beginning January 2000. An administrative appeal of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql interim fuel surcharge was filed by certain cities in Travis County \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql District Court. Entergy Gulf States cannot predict the outcome of this \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql appeal. The fuel and purchased power expenses contained in this surcharge \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql are subject to the current fuel reconciliation proceeding. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In September 2000, Entergy Gulf States requested an interim surcharge \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to collect the under-recovered fuel and purchased power expenses, including \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accrued interest, incurred from August 1999 through July 2000. In December \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000, the PUCT issued an order approving Entergy Gulf States' request for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the collection of $79.0 million over an eleven-month period beginning \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql February 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In January 2001, Entergy Gulf States filed a fuel reconciliation case \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql covering the period from March 1, 1999 to August 31, 2000. Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States is reconciling approximately $583 million of fuel and purchased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power costs. As part of this filing, Entergy Gulf States requested the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql collection of $28 million plus interest of under-recovered fuel and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchased power costs. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In March 2001, Entergy Gulf States filed an application with the PUCT \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql requesting an interim surcharge to collect under-recovered fuel and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchased power expenses incurred from September 2000 through January \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2001. Entergy Gulf States is requesting the recovery of $82 million, plus \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql interest, from July through December 2001. The request is currently pending \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql before the PUCT and an order is expected by June 2001. The fuel and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchased power expenses contained in this surcharge will be subject to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql future fuel reconciliation proceedings. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Filings with the LPSC \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Annual Earnings Reviews (Entergy Corporation and Entergy Gulf States) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In June 2000, the LPSC approved a settlement between Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States and the LPSC staff to refund $83 million, including interest, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql resolving refund issues in Entergy Gulf States' second, third, fourth, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fifth post-merger earnings reviews filed with the LPSC in May 1995, 1996, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1997, and 1998, respectively. The refund was made over a three-month \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql period beginning July 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Although refund issues in the third, fourth, and fifth post-merger \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql earnings reviews were resolved by the June 2000 settlement, certain \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql prospective issues remained in dispute following the settlement. On remand \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql from the Louisiana Supreme Court in the third earnings review, Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States' allowed return on common equity was reset at 10.83%. The fourth \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql earnings review is currently on appeal at the Nineteenth Judicial District \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Court. A final decision from the LPSC in the fifth earnings review is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expected in the first or second quarter of 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In May 1999, Entergy Gulf States filed its sixth required post-merger \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql earnings analysis with the LPSC. Hearings were held in February and June \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2000. The timing of a final decision in the proceeding is not certain. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In May 2000, Entergy Gulf States filed its seventh required post- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql merger earnings analysis with the LPSC. This filing will be subject to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql review by the LPSC, which may result in a change in rates. Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States also is proposing that the allowed return on common equity be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increased to 11.60%. Hearings are scheduled for April 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Formula Rate Plan Filings (Entergy Corporation and Entergy Louisiana) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In May 1997, Entergy Louisiana made its second annual performance- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql based formula rate plan filing with the LPSC for the 1996 test year. This \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql filing resulted in a total rate reduction of approximately $54.5 million, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql which was implemented in July 1997. At the same time, rates were reduced \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by an additional $0.7 million and by an additional $2.9 million effective \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql March 1998. Upon completion of the hearing process in December 1998, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LPSC issued an order requiring an additional rate reduction and refund, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql although the resulting amounts were not quantified. Entergy Louisiana has \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql appealed this order and obtained a preliminary injunction pending a final \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decision on appeal. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In April 1999, Entergy Louisiana submitted its fourth annual \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql performance-based formula rate plan filing for the 1998 test year. A rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reduction of $15.0 million was implemented effective August 1, 1999. In \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql May 2000, the LPSC ordered a $6.4 million refund. This refund was made in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql July 2000. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In May 2000, Entergy Louisiana submitted its fifth annual performance- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql based formula rate plan filing for the 1999 test year. As a result of this \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql filing, Entergy Louisiana implemented a $24.8 million base rate reduction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in August 2000. Entergy Louisiana is proposing to increase prospectively \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the allowed return on common equity from 10.5 % to 11.6%, which, if \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approved, would reduce the amount of any rate reduction implemented. This \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql filing will be subject to review by the LPSC. A procedural schedule has not \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql yet been established by the LPSC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql As approved by the LPSC, Entergy Louisiana will continue its annual \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql performance-based formula rate plan filings for an additional year with a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql filing to be made in April 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel Adjustment Clause Litigation (Entergy Corporation and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In May 1998, a group of ratepayers filed a complaint against Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Corporation, Entergy Power, and Entergy Louisiana in state court in Orleans \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Parish purportedly on behalf of all Entergy Louisiana ratepayers. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql plaintiffs seek treble damages for alleged injuries arising from alleged \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql violations by the defendants of Louisiana's antitrust laws in connection \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql with the costs included in fuel filings with the LPSC and passed through to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ratepayers. Among other things, the plaintiffs allege that Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana improperly introduced certain costs into the calculation of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel charges, including high-cost electricity imprudently purchased from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql its affiliates and high-cost gas imprudently purchased from independent \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql third party suppliers. In addition, plaintiffs seek to recover interest \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and attorneys' fees. Plaintiffs also requested that the LPSC initiate a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql review of Entergy Louisiana's monthly fuel adjustment charge filings and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql force restitution to ratepayers of all costs that the plaintiffs allege \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql were improperly included in those fuel adjustment filings. A few parties \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql have intervened in the LPSC proceeding. In direct testimony, plaintiffs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purport to quantify many of their claims for the period 1989 through 1998 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in an amount totaling $544 million, plus interest. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Louisiana has reached an agreement in principle with the LPSC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql staff for the settlement of the matter before the LPSC and has executed a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql definitive agreement with the plaintiffs for the settlement of the matter \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql before the LPSC and the state court. The LPSC approved the settlement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql agreement following a fairness hearing before an ALJ in November 2000. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Plaintiffs have sought class certification and approval of the settlement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by the state court, and a hearing on those issues is scheduled for April \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Under the terms of the settlement agreement, Entergy Louisiana agrees \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to refund to customers approximately $72 million to resolve all claims \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql arising out of or relating to Entergy Louisiana's fuel adjustment clause \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql filings from January 1, 1975 through December 31, 1999, except with respect \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to purchased power and associated costs included in the fuel adjustment \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql clause filings for the period May 1 through September 30, 1999. Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana previously provided reserves for the refund. Under the terms of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the settlement, Entergy Louisiana also consents to future fuel cost \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovery under a long-term gas contract based on a formula that would \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql likely result in an under-recovery of actual costs under that contract for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the remainder of its term, which runs through 2013. The future under- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovery cannot be precisely estimated at this time because it will depend \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql upon factors that are not certain, such as the price of gas and the amount \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of gas purchased under the long-term contract. In recent years, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana has made purchases under that contract totaling from $91 million \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to $121 million annually. Had the proposed settlement terms been \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql applicable to such purchases, the under-recoveries would have ranged from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $4 million to $9 million per year. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Filings with the MPSC \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Formula Rate Plan Filings (Entergy Corporation and Entergy Mississippi) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In March 2000, Entergy Mississippi submitted its annual performance- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql based formula rate plan for the 1999 test year. The filing indicated that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql no change in rate levels was warranted and the current rate levels remain \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in effect. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In March 1999, Entergy Mississippi submitted its annual performance- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql based formula rate plan filing for the 1998 test year. In April 1999, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MPSC approved a prospective rate reduction of $13.3 million, effective May \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999. In June 1999, Entergy Mississippi revised its March 1999 filing to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql include a portion of refinanced long-term debt not included in the original \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql filing. This revision resulted in an additional rate reduction of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approximately $1.5 million, effective July 1999. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql MPSC Fuel Cost Review (Entergy Corporation and Entergy Mississippi) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In December 2000, the MPSC approved an increase in Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi's energy cost recovery rider to collect the under-recovered \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel and purchased power costs incurred as of September 30, 2000. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovery of $136.7 million, plus carrying charges, will occur over a 24- \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql month period effective with the first billing cycle of January 2001. As \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approved by the MPSC, Entergy Mississippi will be making quarterly energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql cost recovery filings beginning in January 2001 to reflect under-recovered \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel and purchased power costs from the second prior calendar quarter. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Filings with the Council \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1997 Settlement (Entergy Corporation and Entergy New Orleans) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans submitted its cost of service and revenue \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql requirement filing in September 1997 to the Council. In connection with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql this filing, Entergy New Orleans filed a settlement agreement with the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Council, which was approved in November 1998. The settlement agreement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql required the following: \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o base rate reductions for Entergy New Orleans' electric customers of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $7.1 million effective January 1, 1999, $3.2 million effective October 1, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1999, and $16.1 million effective October 1, 2000; \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o a base rate reduction for Entergy New Orleans' gas customers of $1.9 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million effective January 1999; and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql o no base rate increases prior to October 1, 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Natural Gas (Entergy Corporation and Entergy New Orleans) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The Council held hearings in May 1999 regarding the prudence of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans' natural gas purchasing practices. Entergy New Orleans \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql made an offer to settle this matter in conjunction with the offer to settle \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the gas retail open access issue, and the offer was accepted by the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Council. Management has provided adequate reserves for the outcome of this \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql proceeding. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Fuel Adjustment Clause Litigation (Entergy Corporation and Entergy New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In April 1999, a group of ratepayers filed a complaint against Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans, Entergy Corporation, Entergy Services, and Entergy Power in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql state court in Orleans Parish purportedly on behalf of all Entergy New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans ratepayers. The plaintiffs seek treble damages for alleged \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql injuries arising from the defendants' alleged violations of Louisiana's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql antitrust laws in connection with certain costs passed on to ratepayers in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans' fuel adjustment filings with the Council. In \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql particular, plaintiffs allege that Entergy New Orleans improperly included \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql certain costs in the calculation of fuel charges and that Entergy New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans imprudently purchased high-cost fuel from other Entergy affiliates. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Plaintiffs allege that Entergy New Orleans and the other defendant Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql companies conspired to make these purchases to the detriment of Entergy New \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Orleans' ratepayers and to the benefit of Entergy's shareholders, in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql violation of Louisiana's antitrust laws. Plaintiffs also seek to recover \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql interest and attorneys' fees. Exceptions to the plaintiffs' allegations \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql were filed by Entergy, asserting, among other things, that jurisdiction \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql over these issues rests with the Council and FERC. If necessary, at the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql appropriate time, Entergy will also raise its defenses to the antitrust \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql claims. At present, the suit in state court is stayed by stipulation of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the parties. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Plaintiffs also filed this complaint with the Council in order to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql initiate a review by the Council of the plantiffs' allegations and to force \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql restitution to ratepayers of all costs they allege were improperly and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql imprudently included in the fuel adjustment filings. Discovery has begun \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql in the proceedings before the Council. In April 2000, testimony was filed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql on behalf of the plaintiffs in this proceeding. The testimony asserts, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql among other things, that Entergy New Orleans and other defendants have \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql engaged in fuel procurement and power purchasing practices that could have \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql resulted in New Orleans customers being overcharged by more than $59 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million over a period of years. However, it is not clear precisely what \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql periods and damages are being alleged. Entergy intends to defend this \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql matter vigorously, both in court and before the Council. Hearings will be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql held in October 2001. The ultimate outcome of the lawsuit and the Council \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql proceeding cannot be predicted at this time. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Purchased Power for Summer 2000 (Entergy Corporation, Entergy Arkansas, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States, Entergy Louisiana, Entergy Mississippi, and Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql New Orleans) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The domestic utility companies filed applications with the APSC, the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql LPSC, the MPSC, and the Council to approve the sale of power by Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf States from its unregulated, undivided 30% interest in River Bend \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql formerly owned by Cajun to the other domestic utility companies during the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql summer of 2000. In addition, Entergy Gulf States and Entergy Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql filed an application with the LPSC for authorization to purchase capacity \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and electric power from third parties for the summer of 2000. The \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql commissions and Council approved the applications, with a reservation of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql their right to review the prudence of the purchases and the appropriate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql categorization of the costs as either capacity or energy charges for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purposes of recovery. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The LPSC reviewed the purchases and found that Entergy Louisiana's and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States' costs were prudently incurred, but decided that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approximately 34% of the costs should be categorized as capacity charges, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and therefore should be recovered through base rates and not through the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql fuel adjustment clause. In November 2000, the LPSC ordered refunds of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql $11.1 million for Entergy Louisiana and $3.6 million for Entergy Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql States, for which adequate reserves have been made. These costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql categorized as capacity charges will be included in the costs of service \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql used to determine the base rates of those companies. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql River Bend Cost Deferrals (Entergy Corporation and Entergy Gulf States) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Gulf States was amortizing $182 million of River Bend \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql operating and purchased power costs, depreciation, and accrued carrying \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql charges over a 20-year period. In accordance with the June 1999 Texas \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql settlement agreement discussed above, Entergy Gulf States reduced these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deferred costs by $93.9 million, for which adequate reserves had been \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recorded. Entergy Gulf States also was allowed to amortize the remainder \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the accelerated balance as of January 1, 1999, over three years on a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql straight-line basis ending December 31, 2001. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Grand Gulf 1 Deferrals and Retained Shares \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (Entergy Corporation and Entergy Arkansas) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Under the settlement agreement entered into with the APSC in 1985 and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amended in 1988, Entergy Arkansas retains 22% of its 36% share of Grand \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Gulf 1-related costs and recovers the remaining 78% of its share in rates. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In the event that Entergy Arkansas is not able to sell its retained share \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to third parties, it may sell such energy to its retail customers at a \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql price equal to its avoided energy cost, which is currently less than \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas' cost of energy from its retained share. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (Entergy Corporation and Entergy Louisiana) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In a series of LPSC orders, court decisions, and agreements from late \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1985 to mid-1988, Entergy Louisiana was granted rate relief with respect to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs associated with Entergy Louisiana's share of capacity and energy from \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Grand Gulf 1, subject to certain terms and conditions. Entergy Louisiana \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql retains and does not recover from retail ratepayers, 18% of its 14% share \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the costs of Grand Gulf 1 capacity and energy and recovers the remaining \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 82% of its share in rates. Entergy Louisiana is allowed to recover through \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the fuel adjustment clause 4.6 cents per KWH for the energy related to its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql retained portion of these costs. Non-fuel operation and maintenance costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for Grand Gulf 1 are recovered through Entergy Louisiana's base rates. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Alternatively, Entergy Louisiana may sell such energy to nonaffiliated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql parties at prices above the fuel adjustment clause recovery amount, subject \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to the LPSC's approval. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (Entergy Corporation and Entergy New Orleans) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Under various rate settlements with the Council in 1986, 1988, and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1991, Entergy New Orleans agreed to absorb and not recover from ratepayers \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql a total of $96.2 million of its Grand Gulf 1 costs. Entergy New Orleans \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql was permitted to implement annual rate increases in decreasing amounts each \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql year through 1995, and to defer certain costs and related carrying charges \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql for recovery on a schedule extending from 1991 through 2001. As of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 31, 2000, the uncollected balance of Entergy New Orleans' deferred \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs was $11 million. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FERC Settlement (Entergy Corporation and System Energy) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In November 1994, FERC approved an agreement settling a long-standing \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql dispute involving income tax allocation procedures of System Energy. In \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accordance with the agreement, System Energy will refund a total of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approximately $62 million, plus interest, to Entergy Arkansas, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Louisiana, Entergy Mississippi, and Entergy New Orleans through June 2004. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy also reclassified from utility plant to other deferred debits \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql approximately $81 million of other Grand Gulf 1 costs. Although such costs \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql are excluded from rate base, System Energy is amortizing and recovering \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql these costs over a 10-year period. Interest on the $62 million refund and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the loss of the return on the $81 million of other Grand Gulf 1 costs will \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql reduce Entergy's and System Energy's net income by approximately $10 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql million annually. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Proposed Rate Increase \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (System Energy) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy applied to FERC in May 1995 for a $65.5 million rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increase. The request sought changes to System Energy's rate schedule, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql including increases in the revenue requirement associated with \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decommissioning costs, the depreciation rate, and the rate of return on \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql common equity. The request also includes a proposed change in the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql accounting recognition of nuclear refueling outage costs from that of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql expensing those costs as incurred to the deferral and amortization method \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql described in Note 1 to the financial statements. In December 1995, System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Energy implemented the $65.5 million rate increase, subject to refund, for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql which a portion has been reserved. After holding hearings in 1996, a FERC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql ALJ found that portions of System Energy's request should be rejected, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql including a proposed increase in return on common equity from 11% to 13% \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and a requested change in decommissioning cost methodology. The ALJ \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recommended a decrease in the return on common equity from 11% to 10.8%. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Other portions of System Energy's request for a rate increase were approved \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by the ALJ. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql After a hearing, FERC issued an order in July 2000 in the proceeding. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FERC affirmed the ALJ's adoption of a 10.8% return on equity, but modified \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the return to reflect changes in capital market conditions since the ALJ's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decision. FERC adjusted the rate of return to 10.58% for the period \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 1995 to the date of FERC's decision, and prospectively adjusted \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the rate of return to 10.94% from the date of FERC's decision. FERC's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql decision also changed other aspects of System Energy's proposed rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql schedule, including the depreciation rate and decommissioning costs and \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql their methodology. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql System Energy has provided reserves for a potential refund to the rate \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql level of the initial ALJ decision, including interest. Management has \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql analyzed the effect of FERC's decision, and, given the reserve in place, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql has concluded that a refund to the FERC decision rate level is not expected \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to have a material adverse effect on Entergy's, System Energy's, or the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql domestic utility companies' results of operations. System Energy has filed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql a request for rehearing of FERC's order, which defers any refunds until \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql after further FERC action. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (Entergy Mississippi) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Mississippi's allocation of the proposed System Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql wholesale rate increase is $21.6 million annually. In July 1995, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi filed a schedule with the MPSC that defers the retail recovery \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql of the System Energy rate increase. The deferral plan, which was approved \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by the MPSC, began in December 1995, the effective date of the System \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Energy rate increase, and will end after the issuance of a final order by \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql FERC. Under this plan, the deferral period was anticipated to have ended \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql by September 1998, and the deferred amount would have been amortized over \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 48 months beginning in October 1998. Entergy Mississippi filed a revised \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deferral plan with the MPSC in August 1998 that provided for recovery, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql effective with October 1998 billings, of $11.8 million of the System Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql rate increase that was approved by the FERC ALJ's initial decision in July \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1996. The $11.8 million was being amortized over the original 48-month \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql period, which began in October 1998. In August 2000, as a result of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql July 2000 FERC Order and Entergy's request for rehearing, Entergy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Mississippi filed a second revised deferral plan with the MPSC that \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql provides for a one year suspension of the recovery of the ALJ amount \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql deferred prior to October 1998. The amount of System Energy's proposed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql increase in excess of the $11.8 million will also continue to be deferred \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql until the issuance of a final order by FERC, or October 2002, whichever \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql occurs first. These deferred amounts, plus carrying charges, will be \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amortized over a 36-month period beginning in October 2002. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (Entergy New Orleans) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans' allocation of the proposed System Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql wholesale rate increase is $11.1 million annually. In February 1996, \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy New Orleans filed a plan with the Council to defer 50% of the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql amount of the System Energy rate increase. The deferral began in February \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 1996 and will end after the issuance of a final order by FERC. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Grand Gulf Accelerated Recovery Tariff \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (Entergy Arkansas) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In April 1998, FERC approved the Grand Gulf Accelerated Recovery \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Tariff (GGART) that Entergy Arkansas filed as part of the settlement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql agreement that the APSC approved in December 1997. The GGART was designed \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql to allow Entergy Arkansas to pay down a portion of its Grand Gulf purchased \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql power obligation in advance of the implementation of retail access in \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Arkansas. The GGART provides for the acceleration of $165.3 million of its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql obligation over the period January 1, 1999 through June 30, 2004. In \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 2000, the APSC approved an amendment to the settlement agreement \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql that directed Entergy Arkansas to seek FERC approval for the cessation of \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql the GGART as of July 1, 2001. The settlement agreement with the APSC is \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql discussed above in "Filings with the APSC". \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (Entergy Mississippi) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In September 1998, FERC approved the GGART for Entergy Mississippi's \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql allocable portion of Grand Gulf, which was filed with FERC in August 1998. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql The GGART provides for the acceleration of Entergy Mississippi's Grand Gulf \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql purchased power obligation in an amount totaling $221.3 million over the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql period October 1, 1998 through June 30, 2004. \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql December 2000 Ice Storms (Entergy Arkansas) \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql In mid- and late December 2000, two separate ice storms left 226,000 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql and 212,500 Arkansas customers, respectively, without electric power in its \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql service area. The storms were the most severe natural disasters ever to \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql affect Entergy Arkansas, causing damage to transmission and distribution \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql lines, equipment, poles, and facilities. Of the $195 million of estimated \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql storm-related costs, approximately $23 million were capitalized in 2000. \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Entergy Arkansas has applied 2000 excess earnings to offset some of these \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql costs, and Entergy Arkansas intends to seek approval from the APSC for \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql recovery of the remaining storm-related costs. Historically, the APSC \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql has allowed recovery of costs associated with the restoration of service \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql from storms and other natural disasters. \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql NOTE 3. INCOME TAXES \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Income tax expenses for 2000, 1999, and 1998 consist of the following \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql (in thousands): \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql 2000 Entergy Entergy Entergy Entergy Entergy System \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Entergy Arkansas Gulf States Louisiana Mississippi New Orleans Energy \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Current: \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Federal $291,616 $51,042 $42,587 $83,369 ($24,598) $10,530 $132,725 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Foreign 11,555 - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql State 51,293 9,694 6,737 12,926 (3,615) 1,706 19,750 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql --------------------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Total 354,464 60,736 49,324 96,295 (28,213) 12,236 152,475 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Deferred -- net 150,018 46,365 61,779 22,111 52,581 (129) (67,509) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Investment tax credit \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql adjustments -- net (25,561) (6,589) (7,500) (5,761) (1,500) (510) (3,703) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql --------------------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Recorded income tax expense $478,921 $100,512 $103,603 $112,645 $22,868 $11,597 $81,263 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql =========================================================================== \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql 1999 Entergy Entergy Entergy Entergy Entergy System \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Entergy Arkansas Gulf States Louisiana Mississippi New Orleans Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Current: \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Federal $452,568 $25,811 $64,991 $115,180 ($660) $13,238 $121,733 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Foreign 27,730 - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql State 65,834 5,780 11,669 22,675 131 2,923 18,979 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ------------------------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Total 546,132 31,591 76,660 137,855 (529) 16,161 140,712 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Deferred -- net (153,304) 26,335 13,513 (9,953) 19,566 (2,615) (77,173) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Investment tax credit \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql adjustments -- net (36,161) (3,914) (15,008) (5,534) (1,500) (516) (9,688) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ------------------------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Recorded income tax expense $356,667 54,012 $75,165 $122,368 $17,537 $13,030 $53,851 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql =============================================================================== \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql 1998 Entergy Entergy Entergy Entergy Entergy System \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Entergy Arkansas Gulf States Louisiana Mississippi New Orleans Energy \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Current: \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Federal $235,979 $68,814 $43,729 $69,551 $34,984 $15,010 $91,107 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Foreign 28,156 - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql State 67,163 14,853 17,218 12,643 5,541 2,530 14,378 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ------------------------------------------------------------------------------ \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Total 331,298 83,667 60,947 82,194 40,525 17,540 105,485 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Deferred -- net (109,474) (7,153) (90,314) 32,506 (10,983) (6,993) (24,745) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Investment tax credit \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql adjustments -- net 44,911 (5,140) 61,140 (5,596) (1,511) (505) (3,477) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ------------------------------------------------------------------------------ \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Recorded income tax expense $266,735 $71,374 $31,773 $109,104 $28,031 $10,042 $77,263 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ============================================================================== \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Total income taxes differ from the amounts computed by applying the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql statutory income tax rate to income before taxes. The reasons for the \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql differences for the years 2000, 1999, and 1998 are (amounts in thousands): \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Entergy Entergy Entergy Entergy Entergy System \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql 2000 Entergy Arkansas Gulf States Louisiana Mississippi New Orleans Energy \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Computed at statutory rate (35%) $416,443 $83,147 $99,380 $96,363 $21,644 $9,840 $61,253 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Increases (reductions) in tax \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql resulting from: \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql State income taxes net of \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql federal income tax effect 47,504 11,571 14,421 11,389 2,239 824 7,060 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Depreciation 49,741 16,098 4,791 10,810 1,346 1,441 15,255 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Amortization of investment \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql tax credits (23,783) (5,112) (7,664) (5,520) (1,500) (507) (3,480) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Flow-through/permanent \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql differences (18,495) (5,596) (10,032) (1,623) (825) (401) (18) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql US tax on foreign income 1,472 - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Other -- net 6,039 404 2,707 1,226 (36) 400 1,193 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ----------------------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Total income taxes $478,921 $100,512 $103,603 $112,645 $22,868 $11,597 $81,263 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ============================================================================= \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Effective Income Tax Rate 40.3% 42.3% 36.5% 40.9% 37.0% 41.2% 46.4% \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Entergy Entergy Entergy Entergy Entergy System \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql 1999 Entergy Arkansas Gulf States Louisiana Mississippi New Orleans Energy \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Computed at statutory rate (35%) $333,093 $43,164 $70,058 $109,948 $20,693 $11,196 $47,678 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Increases (reductions) in tax \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql resulting from: \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql State income taxes net of \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql federal income tax effect 49,487 6,949 18,805 13,741 1,982 1,930 6,080 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Depreciation 49,460 18,429 4,718 9,577 (1,093) 2,232 15,597 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Amortization of investment \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql tax credits (29,015) (5,132) (6,642) (5,532) (1,500) (518) (9,691) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Flow-through/permanent \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql differences (8,042) (5,250) (2,795) (1,191) (284) (272) 27 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql US tax benefit on foreign income (9,584) - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Benefit of Entergy Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql expenses - (3,341) (4,046) (4,053) (1,936) (754) (4,552) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Change in valuation allowance (46,315) - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Other -- net 17,583 (807) (4,933) (122) (325) (784) (1,288) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ----------------------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Total income taxes $356,667 $54,012 $75,165 $122,368 $17,537 $13,030 $53,851 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ============================================================================= \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Effective Income Tax Rate 37.5% 43.8% 37.6% 39.0% 29.7% 40.7% 39.5% \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Entergy Entergy Entergy Entergy Entergy System \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql 1998 Entergy Arkansas Gulf States Louisiana Mississippi New Orleans Energy \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Computed at statutory rate (35%) $368,327 $63,814 $27,358 $101,007 $31,734 $9,162 $64,309 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Increases (reductions) in tax \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql resulting from: \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql State income taxes net of \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql federal income tax effect 37,494 9,289 7,744 9,156 3,053 831 7,421 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Depreciation 40,578 6,497 11,099 8,147 (686) 888 14,633 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Amortization of investment \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql tax credits (21,285) (5,136) (5,061) (5,592) (1,512) (504) (3,480) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Flow-through/permanent \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql differences (3,570) 1,078 (4,404) (848) 149 (187) (18) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql US tax on foreign income 108,194 - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Non-taxable gain on sale \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql of foreign assets (20,283) - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Change in UK statutory rate (31,703) - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Foreign subsidiary basis difference (58,235) - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Reduced rate on gain on sale \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql of foreign assets (56,712) - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Non-deductible franchise fees 7,315 - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Interest on perpetual instruments (5,467) - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Benefit of Entergy Corporation \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql expenses - (5,212) (4,948) (3,947) (2,386) (629) (4,999) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Change in valuation allowance (106,636) - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Other -- net 8,718 1,044 (15) 1,181 (2,321) 481 (603) \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ------------------------------------------------------------------------------ \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Total income taxes $266,735 $71,374 $31,773 $109,104 $28,031 $10,042 $77,263 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql ============================================================================== \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs14\ql Effective Income Tax Rate 25.3% 39.1% 40.6% 37.8% 30.9% 38.4% 42.1% \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql Significant components of net deferred tax liabilities as of December \par\pard\plain\fs16\pard\plain\cf1\f50\fs16\ql 31, 2000 and 1999 are as follows (in thousands): \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql 2000 Entergy Entergy Entergy Entergy Entergy System \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Entergy Arkansas Gulf States Louisiana Mississippi New Orleans Energy \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Deferred Tax Liabilities: \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Net regulatory assets/(liabilities) ($1,193,795) ($197,577) ($448,460) ($249,983) ($32,968) $9,755 ($274,562) \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Plant-related basis differences (3,073,388) (536,667) (1,034,502) (746,275) (216,102) (65,066) (413,200) \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Rate deferrals (159,147) (17,554) (1,594) - (111,044) (28,955) - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Other (223,095) (132,928) (9,971) (60,390) (4,052) (2,682) (17,019) \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql -------------------------------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Total (4,649,425) (884,726) (1,494,527) (1,056,648) (364,166) (86,948) (704,781) \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql -------------------------------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Deferred Tax Assets: \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Accumulated deferred investment \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql tax credit 168,841 34,626 44,526 45,173 7,424 2,852 34,240 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Capital loss carryforwards 39,091 - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Foreign tax credits 98,468 - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Sale and leaseback 229,169 - - 103,200 - - 125,969 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Removal cost 105,842 872 27,101 65,690 203 11,976 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Unbilled revenues 25,790 - 13,143 - 4,845 7,802 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Pension-related items 27,554 - 7,874 7,889 (2,335) 6,217 2,926 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Rate refund 152,408 - 25,607 35,803 - - 123,306 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Reserve for regulatory adjustments 117,437 - 117,437 - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Transition cost accrual 43,568 43,568 - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Other 259,938 34,642 49,688 20,986 - 7,804 25,187 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Valuation allowance (93,413) - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql --------------------------------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Total 1,174,693 113,708 285,376 278,741 10,137 36,651 311,628 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql --------------------------------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Net deferred tax liability ($3,474,732) ($771,018) ($1,209,151) ($777,907) ($354,029) ($50,297) ($393,153) \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql ======================================================================================= \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql 1999 Entergy Entergy Entergy Entergy Entergy System \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Entergy Arkansas Gulf States Louisiana Mississippi New Orleans Energy \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Deferred Tax Liabilities: \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Net regulatory assets/(liabilities) ($1,268,257) ($229,555) ($432,256) ($278,289) ($32,048) $4,480 ($300,589) \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Plant-related basis differences (3,041,135) (533,375) (1,013,110) (749,257) (220,827) (62,104) (452,083) \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Rate deferrals (77,652) (6,168) (3,128) - (44,214) (24,142) - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Other (201,958) (77,812) (15,157) (24,741) (9,214) (7,718) (22,412) \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql -------------------------------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Total (4,589,002) (846,910) (1,463,651) (1,052,287) (306,303) (89,484) (775,084) \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql -------------------------------------------------------------------------------------- \par\pard\plain\fs16 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Deferred Tax Assets: \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Accumulated deferred investment \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql tax credit 178,153 37,211 46,851 47,390 7,997 3,048 35,656 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Net operating loss carryforwards 2,137 - 2,137 - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Capital loss carryforwards 62,754 - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Foreign tax credits 116,701 - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Alternative minimum tax credit 40,658 - 40,658 - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Sale and leaseback 230,690 - - 107,184 - - 123,506 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Removal cost 108,572 943 26,848 66,786 1,994 12,001 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Unbilled revenues 40,761 - 21,161 17,618 (1,183) 3,165 - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Pension-related items 32,734 - 10,810 9,509 (1,508) 8,064 2,883 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Rate refund 142,984 - 45,781 20,270 - 1,347 102,422 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Reserve for regulatory adjustments 124,078 - 124,078 - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Transition cost accrual 43,127 43,127 - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql FERC Settlement 12,638 - - - - - 12,638 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Other 161,074 13,358 18,485 3,760 - 7,118 8,872 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Valuation allowance (91,039) - - - - - - \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql ------------------------------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Total 1,206,022 94,639 336,809 272,517 7,300 34,743 285,977 \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql ------------------------------------------------------------------------------------- \par\pard\plain\fs16\pard\plain\cf1\f50\fs12\ql Net deferred tax liability ($3,382,980) ($752,271) ($1,126,842) ($779,770) ($299,003) ($54,741) ($489,107) \par\pard\plain\fs16\pard\plain\cf1\f