__________________________________________________________________________
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
X QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For the Quarterly Period Ended September 30, 2001
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from ____________ to ____________
Commission Registrant, State of Incorporation, I.R.S. Employer
File Number Address of Principal Executive Identification No.
Offices and Telephone Number
1-11299 ENTERGY CORPORATION 72-1229752
(a Delaware corporation)
639 Loyola Avenue
New Orleans, Louisiana 70113
Telephone (504) 576-4000
1-10764 ENTERGY ARKANSAS, INC. 71-0005900
(an Arkansas corporation)
425 West Capitol Avenue, 40th Floor
Little Rock, Arkansas 72201
Telephone (501) 377-4000
1-27031 ENTERGY GULF STATES, INC. 74-0662730
(a Texas corporation)
350 Pine Street
Beaumont, Texas 77701
Telephone (409) 838-6631
1-8474 ENTERGY LOUISIANA, INC. 72-0245590
(a Louisiana corporation)
4809 Jefferson Highway
Jefferson, Louisiana 70121
Telephone (504) 840-2734
0-320 ENTERGY MISSISSIPPI, INC. 64-0205830
(a Mississippi corporation)
308 East Pearl Street
Jackson, Mississippi 39201
Telephone (601) 368-5000
0-5807 ENTERGY NEW ORLEANS, INC. 72-0273040
(a Louisiana corporation)
1600 Perdido Street, Building 505
New Orleans, Louisiana 70112
Telephone (504) 670-3674
1-9067 SYSTEM ENERGY RESOURCES, INC. 72-0752777
(an Arkansas corporation)
Echelon One
1340 Echelon Parkway
Jackson, Mississippi 39213
Telephone (601) 368-5000
__________________________________________________________________________
Indicate by check mark whether the registrants (1) have filed all
reports required to be filed by Section 13 or 15(d) of the Securities
Exchange Act of 1934 during the preceding 12 months (or for such shorter
period that the registrants were required to file such reports), and (2)
have been subject to such filing requirements for the past 90 days.
Yes X No
Common Stock Outstanding Outstanding at October 31, 2001
Entergy Corporation ($0.01 par value) 221,039,413
Entergy Corporation, Entergy Arkansas, Inc., Entergy Gulf States,
Inc., Entergy Louisiana, Inc., Entergy Mississippi, Inc., Entergy New
Orleans, Inc., and System Energy Resources, Inc. separately file this
combined Quarterly Report on Form 10-Q. Information contained herein
relating to any individual company is filed by such company on its own
behalf. Each company reports herein only as to itself and makes no other
representations whatsoever as to any other company. This combined
Quarterly Report on Form 10-Q supplements and updates the Annual Report on
Form 10-K for the calendar year ended December 31, 2000, and the Quarterly
Reports on Form 10-Q for the quarters ended March 31, 2001 and June 30,
2001, filed by the individual registrants with the SEC, and should be read
in conjunction therewith.
Forward-Looking Information
The following constitutes a "Safe Harbor" statement under the Private
Securities Litigation Reform Act of 1995: Investors are cautioned that
forward-looking statements contained herein with respect to the revenues,
earnings, performance, strategies, prospects and other aspects of the
business of Entergy Corporation, Entergy Arkansas, Inc., Entergy Gulf
States, Inc., Entergy Louisiana, Inc., Entergy Mississippi, Inc., Entergy
New Orleans, Inc., and System Energy Resources, Inc. and their affiliated
companies may involve risks and uncertainties. A number of factors could
cause actual results or outcomes to differ materially from those indicated
by such forward-looking statements. These factors include, but are not
limited to, risks and uncertainties relating to: the effects of weather,
the performance of generating units and transmission systems, the
possession of nuclear materials, fuel and purchased power prices and
availability, the effects of regulatory decisions and changes in law,
litigation, capital spending requirements, the onset of competition,
including the ability to recover net regulatory assets and other potential
stranded costs, the effects of recent developments in the California
electricity market on the utility industry nationally, advances in
technology, changes in accounting standards, corporate restructuring and
changes in capital structure, the success of new business ventures,
changes in the markets for electricity and other energy-related
commodities, changes in interest rates and in financial and foreign
currency markets generally, the economic climate and growth in Entergy's
service territories, changes in corporate strategies, and other factors.
ENTERGY CORPORATION AND SUBSIDIARIES
INDEX TO QUARTERLY REPORT ON FORM 10-Q
September 30, 2001
Page Number
Definitions 1
Management's Financial Discussion and Analysis -
Significant Factors and Known Trends 3
Management's Financial Discussion and Analysis -
Liquidity and Capital Resources 7
Results of Operations and Financial Statements:
Entergy Corporation and Subsidiaries:
Results of Operations 13
Consolidated Statements of Income 21
Consolidated Statements of Cash Flows 22
Consolidated Balance Sheets 24
Consolidated Statements of Retained Earnings,
Comprehensive Income, and Paid-In Capital 26
Selected Operating Results 27
Entergy Arkansas, Inc.:
Results of Operations 28
Income Statements 32
Statements of Cash Flows 33
Balance Sheets 34
Selected Operating Results 36
Entergy Gulf States, Inc.:
Results of Operations 37
Income Statements 40
Statements of Cash Flows 41
Balance Sheets 42
Selected Operating Results 44
Entergy Louisiana, Inc.:
Results of Operations 45
Income Statements 48
Statements of Cash Flows 49
Balance Sheets 50
Selected Operating Results 52
Entergy Mississippi, Inc.:
Results of Operations 53
Income Statements 56
Statements of Cash Flows 57
Balance Sheets 58
Selected Operating Results 60
Entergy New Orleans, Inc.:
Results of Operations 61
Income (Loss) Statements 64
Statements of Cash Flows 65
Balance Sheets 66
Selected Operating Results 68
System Energy Resources, Inc.:
Results of Operations 69
Income Statements 71
Statements of Cash Flows 73
Balance Sheets 74
Notes to Financial Statements for Entergy Corporation
and Subsidiaries 76
Part II:
Item 1. Legal Proceedings 89
Item 4. Submission of Matters to a Vote of Security
Holders 89
Item 5. Other Information 89
Item 6. Exhibits and Reports on Form 8-K 90
Signature 93
DEFINITIONS
Certain abbreviations or acronyms used in the text are defined below:
Abbreviation or Acronym Term
AFUDC Allowance for Funds Used During Construction
ALJ Administrative Law Judge
ANO 1 and 2 Units 1 and 2 of Arkansas Nuclear One Steam
Electric Generating Station (nuclear)
APSC Arkansas Public Service Commission
Board Board of Directors of Entergy Corporation
BPS British pounds sterling
Cajun Cajun Electric Power Cooperative, Inc.
CitiPower CitiPower Pty., an electric distribution company
serving Melbourne, Australia and surrounding
suburbs, which was sold by Entergy effective
December 31, 1998
Council Council of the City of New Orleans, Louisiana
DOE United States Department of Energy
domestic utility
companies Entergy Arkansas, Entergy Gulf States, Entergy
Louisiana, Entergy Mississippi, and Entergy New
Orleans, collectively
EPA United States Environmental Protection Agency
EPDC Entergy Power Development Corporation
EWO Entergy Wholesale Operations, which primarily
consists of Entergy's global power development
business
Entergy Entergy Corporation and its various direct and
indirect subsidiaries
Entergy Arkansas Entergy Arkansas, Inc.
Entergy Gulf States Entergy Gulf States, Inc., including its wholly
owned subsidiaries - Varibus Corporation, GSG&T,
Inc., Prudential Oil & Gas, Inc., and Southern
Gulf Railway Company
Entergy-Koch Entergy-Koch, L.P., a joint venture equally owned
by Entergy and Koch Industries, Inc.
Entergy London Entergy London Investments plc, formerly Entergy
Power UK plc (including its wholly owned
subsidiary, London Electricity plc), which was
sold by Entergy effective December 4, 1998
Entergy Louisiana Entergy Louisiana, Inc.
Entergy Mississippi Entergy Mississippi, Inc.
Entergy New Orleans Entergy New Orleans, Inc.
Entergy Power Entergy Power, Inc.
FERC Federal Energy Regulatory Commission
FitzPatrick James A. FitzPatrick nuclear power plant, 825 MW
facility located near Oswego, New York, purchased
in November 2000, from NYPA by Entergy's domestic
non-utility nuclear business
Form 10-K The combined Annual Report on Form 10-K for the
year ended December 31, 2000 of Entergy, Entergy
Arkansas, Entergy Gulf States, Entergy Louisiana,
Entergy Mississippi, Entergy New Orleans, and
System Energy
Grand Gulf 1 Unit No. 1 of the Grand Gulf Nuclear Generation
Plant
GGART Grand Gulf Accelerated Recovery Tariff
GWH Gigawatt hours, which equals one million kilowatt-
hours
Indian Point 2 Indian Point 2 nuclear power plant, 951 MW
facility located in Westchester County, New York,
purchased in September 2001 from Consolidated
Edison by Entergy's domestic non-utility nuclear
business
Indian Point 3 Indian Point 3 nuclear power plant, 980 MW
facility located in Westchester County, New York,
purchased in November 2000 from NYPA by Entergy's
domestic non-utility nuclear business
Abbreviation or Acronym Term
LDEQ Louisiana Department of Environmental Quality
LPSC Louisiana Public Service Commission
Merger Agreement Agreement and Plan of Merger dated July 30, 2000
by and between FPL Group, Entergy Corporation,
WCB Holding Corporation, Ranger Acquisition
Corporation and Ring Acquisition Corporation,
which was mutually terminated on April 1, 2001
MPSC Mississippi Public Service Commission
MW Megawatt(s), which equals one thousand kilowatt-
hours
Net revenue Operating revenue net of fuel, fuel-related, and
purchased power expenses; other regulatory
credits; and amortization of rate deferrals
NRC Nuclear Regulatory Commission
NYPA New York Power Authority
Pilgrim Pilgrim Nuclear Station, 670 MW facility located
in Plymouth, Massachusetts, purchased in July
1999 from Boston Edison by Entergy's domestic non-
utility nuclear business
PUCT Public Utility Commission of Texas
PUHCA Public Utility Holding Company Act of 1935, as
amended
River Bend River Bend Steam Electric Generating Station
(nuclear)
SEC Securities and Exchange Commission
SFAS Statement of Financial Accounting Standards as
promulgated by the Financial Accounting Standards
Board
System Agreement Agreement, effective January 1, 1983, as
modified, among the domestic utility companies
relating to the sharing of generating capacity
and other power resources
System Energy System Energy Resources, Inc.
Unit Power Sales
Agreement Agreement, dated as of June 10, 1982, as amended
and approved by FERC, among Entergy Arkansas,
Entergy Louisiana, Entergy Mississippi, Entergy
New Orleans, and System Energy, relating to the
sale of capacity and energy from System Energy's
share of Grand Gulf 1
Waterford 3 Unit No. 3 (nuclear) of the Waterford Plant
weather-adjusted usage electric usage excluding the effects of weather
deviations
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
SIGNIFICANT FACTORS AND KNOWN TRENDS
See "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - SIGNIFICANT
FACTORS AND KNOWN TRENDS" in the Form 10-K for a discussion of the
increasing competitive pressures facing Entergy and the electric utility
industry, as well as market risks and other significant issues affecting
Entergy. See "Item 1. Business - BUSINESS OF ENTERGY - Industry
Restructuring and Competition" in the Form 10-K for issues concerning the
timing and implementation of Entergy's transition to competition,
including potential conflicts among Entergy's regulated jurisdictions.
Set forth below are updates to the information contained therein.
Domestic Transition to Competition
State Regulatory Activity
Arkansas
As discussed in Note 2 to the financial statements in the Form 10-K,
the target date for retail open access has been delayed until no sooner
than October 1, 2003 and no later than October 1, 2005. In September
2001, the APSC staff issued a report recommending the following:
o the APSC use its statutory authority to delay retail open access
until October 1, 2004;
o the APSC recommend to the Arkansas General Assembly that legislation
be enacted to further delay or repeal retail open access, with repeal
as the better approach; and
o further suspension of all rulemaking activity to implement retail
open access.
Entergy Arkansas agreed in reply testimony to the APSC's proposed
additional delay of retail open access, but opposed repeal of deregulation
legislation as premature at this time. A hearing is currently scheduled
for November 2001.
Texas
Since the filing of the Form 10-K, several developments have occurred
in the Texas retail open access proceedings and in Texas and Louisiana
proceedings for the separation of the utility operations of Entergy Gulf
States among new corporate and partnership entities, including delay in
the implementation of retail competition until September 15, 2002. See
Note 2 to the financial statements herein for a discussion of these
developments.
Louisiana
In July 2001, the LPSC staff concluded that retail competition is
not in the public interest at this time for any customer class.
Nevertheless, the LPSC staff has recommended that retail open access be
made available for certain large industrial customers as early as January
2003. An eligible customer choosing open access would be required to
provide its utility with a minimum of six months notice prior to the date
of retail open access. The LPSC staff report also recommended that all
customers who do not currently co- or self-generate, or have co- or self-
generation under construction as of a date specified by the LPSC, remain
liable for their share of stranded costs. During its October 2001 meeting,
the LPSC adopted dates by which a total of 800 MW of co- or self-
generation could be developed in Louisiana without being affected by
stranded costs. During its November 2001 meeting, the LPSC decided not to
adopt a plan for retail open access at this time, but to have
collaborative group meetings concerning open access from time to time,
and to have the LPSC staff monitor developments in neighboring states and
to report to the LPSC regarding the progress of retail access
developments in those states. At this time, no further moves toward
retail access in Louisiana appear likely until sometime during or after
2004.
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
SIGNIFICANT FACTORS AND KNOWN TRENDS
Federal Regulatory Activity
System Agreement Proceedings
See "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - SIGNIFICANT
FACTORS AND KNOWN TRENDS" in the Form 10-K for a discussion of the
proposed amendments to the System Agreement filed with FERC by the
domestic utility companies. The proposed amendments were designed to
facilitate the implementation of retail competition in Arkansas and Texas.
See Note 2 to the financial statements herein for retail competition
developments, including delay in the implementation of retail open access.
As discussed in the Form 10-K, the LPSC and the Council also filed a
complaint with FERC seeking revisions to the System Agreement.
In June 2001, in connection with these proceedings, the parties filed
an offer of settlement with FERC. The offer of settlement provides for
the following amendments to the System Agreement:
o the Texas retail jurisdictional division of Entergy Gulf States will
terminate its participation in the System Agreement, except for the
aspects related to transmission equalization, when Texas implements
retail open access for Entergy Gulf States;
o five percent of Entergy Gulf States' megawatt capacity allocated to
the Texas retail load by the LPSC will be made available to the domestic
utility companies remaining under the System Agreement. Each company has
until December 15, 2001 to elect to purchase its pro rata share of this
capacity. Entergy Arkansas' pro rata share is 27.3%, Entergy Gulf States
- Louisiana's pro rata share is 20.2%, Entergy Louisiana's pro rata share
is 30.2%, Entergy Mississippi's pro rata share is 15.9%, and Entergy New
Orleans' pro rata share is 6.4%. If a company elects to purchase
capacity it will be for the period from the inception of retail open
access in Texas for Entergy Gulf States through June 30, 2008. If a
company elects not to purchase, the other companies are not entitled
to purchase that company's share of the capacity; and
o the service schedule developed to track changes in energy costs
resulting from the Entergy-Gulf States Utilities merger is modified to
include one final true-up of fuel costs when the Texas retail
jurisdictional division of Entergy Gulf States ceases participation in
the System Agreement, after which the service schedule will no longer
be applicable for any purpose.
The proceeding on the complaint filed with FERC in 1995 by the LPSC
requesting modification of the System Agreement to exclude curtailable
load from the cost allocation determination was not settled. In July
2001, an ALJ issued decisions certifying the offer of settlement to the
FERC and generally continuing to include curtailable load served during
1995 in cost allocation determinations. FERC approved the settlement in
July 2001.
As anticipated by the offer of settlement, the LPSC and the Council
commenced a new proceeding at FERC in June 2001. In this proceeding, the
LPSC and the Council allege that the rough production cost equalization
required by FERC under the System Agreement and the Unit Power Sales
Agreement has been disrupted by changed circumstances. The LPSC and the
Council have requested that FERC amend the System Agreement or the Unit
Power Sales Agreement or both to achieve full production cost equalization
or to restore rough production cost equalization. Their complaint does
not seek a change in the total amount of the costs allocated under the
Unit Power Sales Agreement. Several parties have filed interventions in
the proceeding, including the APSC and the MPSC. Entergy filed its
response to the complaint in July 2001 denying the allegations of the LPSC
and the Council. The APSC and the MPSC also filed responses opposing the
relief sought by the LPSC and the Council.
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
SIGNIFICANT FACTORS AND KNOWN TRENDS
In their complaint, the LPSC and Council allege that the domestic
utility companies' annual production costs over the period 2002 to 2007
will be over or (under) the average for the domestic utility companies by
the following amounts:
Entergy Arkansas ($130) to ($278) million
Entergy Gulf States - LA $11 to $87 million
Entergy Louisiana $139 to $132 million
Entergy Mississippi ($27) to $13 million
Entergy New Orleans $7 to $46 million
This range of results is a function of assumptions regarding such things
as future natural gas prices, the future market price of electricity, and
other factors. If FERC grants the relief requested, the relief may result
in a material increase in production costs allocated to companies whose
costs currently are projected to be less than the average and a material
decrease in production costs allocated to companies whose costs currently
are projected to exceed the average. Management believes that any changes
in the allocation of production costs resulting from a FERC decision
should result in similar rate changes for retail customers. Therefore,
management does not believe that this proceeding will have a material
effect on the financial condition of any of the domestic utility
companies, although neither the timing nor the outcome of the proceedings
at FERC can be predicted at this time.
Open Access Transmission and Entergy's Transco Proposal
See "Open Access Transmission and Entergy's Transco Proposal" in
"MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - SIGNIFICANT FACTORS AND
KNOWN TRENDS" in the Form 10-K for a discussion of FERC's Order 2000 and
Entergy's proposed Transco.
In July 2001, FERC issued orders on various proposals for
transmission owners in the United States to commit their assets to
regional transmission organizations (RTOs). In the orders, FERC indicated
that it envisions the establishment of four RTOs in the United States, one
in each of the Northeast, Southeast, Midwest, and West. FERC further
required utilities within the Northeast and Southeast, including Entergy,
to participate in mediation proceedings for the purpose of facilitating
the establishment of these two RTOs. In September 2001 an ALJ issued a
report on the mediation in the Southeast, and a decision from FERC is
pending. The ALJ's recommendation contains a structure that would
continue to allow Entergy to pursue the development of an independent
transmission company that operates within and under the oversight of a
larger RTO.
Transco proceedings with state and local regulatory commissions have
been suspended for the domestic utility companies pending further action
in the FERC-mandated mediation proceedings.
In September 2001, the LPSC ordered Entergy Gulf States and Entergy
Louisiana to show cause as to why these companies should not be enjoined
from transferring their transmission assets to a Transco or any similar
organization, asserting that FERC does not have jurisdiction to mandate a
Transco or RTO. In October 2001, Entergy Gulf States and Entergy
Louisiana filed a response to the LPSC's show cause directives. A
procedural schedule in this proceeding has been established, and hearings
are scheduled for November 2001. The ultimate outcome of this proceeding
cannot be predicted at this time.
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
SIGNIFICANT FACTORS AND KNOWN TRENDS
State and Local Rate Regulation
The domestic utility companies' retail and wholesale rate matters and
other regulatory proceedings are discussed more thoroughly in the Form 10-
K and are updated in Note 2 to the financial statements herein.
Filings with the APSC
In April 2001, Entergy Arkansas filed with the APSC a proposal to
recover costs plus carrying charges associated with power restoration
caused by the December 2000 ice storms. In an order issued in June 2001,
the APSC decided not to give final approval to Entergy Arkansas' proposed
storm cost recovery rider outside of a fully developed cost-of-service
study in a general rate proceeding. The APSC action resulted in the
deferral in 2001 of previously expensed storm damage costs as reflected in
Entergy Arkansas' financial statements. In a subsequent decision, the
APSC ordered Entergy Arkansas to commence such a proceeding by January
2002.
In the subsequent order, the APSC also established a procedural
schedule to consider putting an interim rider in place to recover the ice
storm costs, subject to refund. The schedule calls for a January 2002
hearing date and the issuance of a decision by February 2002. In accord
with the schedule, Entergy Arkansas filed its final storm damage cost
determination, which reflects costs of approximately $195 million. The
filing asks for recovery of approximately $170 million through the rider
over approximately a six and one-half year period. The remainder of the
costs is primarily capital expenditures that will be included in rate
base in the general rate proceeding that is currently scheduled to be
filed in January 2002. No assurance can be give as to the timing or
outcome of these proceedings before the APSC.
Continued Application of SFAS 71 and Stranded Cost Exposure
See "Continued Application of SFAS 71 and Stranded Cost Exposure" in
"MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - SIGNIFICANT FACTORS AND
KNOWN TRENDS" in the Form 10-K for a discussion of the potential effects
of discontinuation of SFAS 71 for the generation portion of Entergy's
business as well as Entergy's exposure to stranded costs. Resolution of
the regulatory proceedings affecting the transition to competition of
Entergy Gulf States' Texas generation business may require the
discontinuance of the application of SFAS 71 accounting treatment to that
business. Management does not expect a material adverse effect on
Entergy's and Entergy Gulf States' results of operations if SFAS 71
accounting treatment for the Texas generation business is discontinued.
The regulatory proceedings in Texas and Louisiana affecting the Texas
transition to competition are discussed in "Domestic Transition to
Competition - State Regulatory and Legislative Activity - Texas" in
"MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS - SIGNIFICANT FACTORS AND
KNOWN TRENDS" in the Form 10-K and that discussion is updated in Note 2 to
the financial statements herein. As discussed in Note 2, several
uncertainties still exist in the transition to competition in Texas,
including the effects of the settlement agreement that the PUCT approved
that delays retail open access until at least September 15, 2002.
Therefore, the criteria under EITF 97-4 for discontinuing SFAS 71
treatment have not been met as of September 30, 2001.
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
SIGNIFICANT FACTORS AND KNOWN TRENDS
Attacks of September 11, 2001
Since the attacks on New York and Washington, D.C. on September 11,
2001, security at Entergy's nuclear power plants has been at a heightened
alert level. Entergy is working with the NRC and other government
agencies on security at the nuclear sites. Based on current security
plans, management does not expect a material effect on Entergy's financial
statements to result from additional security measures that may be
implemented at its nuclear sites. As the NRC, other governmental
entities, and the industry continue to consider security issues, it is
possible that more extensive security plans requiring higher than expected
costs could be required.
Business Combination with FPL Group
On July 30, 2000, Entergy Corporation and FPL Group, Inc. entered
into a Merger Agreement providing for a business combination that would
have resulted in the creation of a new company. On April 1, 2001, Entergy
Corporation and FPL Group terminated the Merger Agreement by mutual
decision. Both companies agreed that no termination fee is payable under
the terms of the Merger Agreement, unless within nine months of the
termination one party agrees to a substantially similar transaction with
another party. Each company will bear its own merger-related expenses.
Entergy has withdrawn its merger-related filings submitted to FERC, the
SEC, and state and local regulatory agencies.
New Accounting Pronouncements
The FASB issued several new accounting pronouncements in mid-2001.
See Note 10 to the financial statements for a discussion of the expected
effects of these pronouncements on Entergy.
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
LIQUIDITY AND CAPITAL RESOURCES
Cash Flows
Operating Activities
Following are net cash flows provided by operating activities for
Entergy, the domestic utility companies, and System Energy for the nine
months ended September 30, 2001 and 2000:
Company 2001 2000
(In Millions)
Entergy $1,228.8 $1,439.2
Entergy Arkansas $186.5 $261.7
Entergy Gulf States $248.9 $242.3
Entergy Louisiana $312.3 $214.5
Entergy Mississippi $63.1 $120.7
Entergy New Orleans $17.2 $10.2
System Energy $322.1 $372.2
Entergy's consolidated net cash flow provided by operating activities
decreased primarily due to:
o a decrease, after eliminating the effect of money pool activity, of
$65 million in cash provided by the domestic utility companies and
System Energy;
o net cash used of $108 million by the energy commodity services
segment thus far in 2001. The energy commodity services segment
includes the EWO business and the Entergy-Koch joint venture. In
2001, EWO used $68 million of net cash in operating activities
compared with EWO providing $30 million of operating cash flow in
2000. This fluctuation is primarily due to a net loss, excluding the
gain on the sale of the Saltend plant, generated in 2001 compared
with net income generated in 2000. Entergy-Koch/power marketing and
trading used $40 million of net cash in operating activities in 2001
compared with power marketing and trading providing $48 million of
operating cash flow in 2000. This fluctuation is primarily because,
although income from this activity is higher in 2001, Entergy has
not received dividends from Entergy-Koch. Entergy did not expect
to receive dividends from Entergy-Koch in 2001 as the joint venture
retains capital for its liquidity needs; and
o an increase, after eliminating the effect of money pool activity, of
$38 million in cash used by the parent company, Entergy Corporation,
primarily due to increased interest costs and the payment of merger-
related costs.
These decreases in consolidated net operating cash flow were
partially offset by a $99 million increase in cash provided by the
domestic non-utility nuclear business, primarily from the operation of the
FitzPatrick and Indian Point 3 plants, purchased in the fourth quarter of
2000.
Payments for power restoration costs associated with the December
2000 ice storms in Arkansas, along with lower net income, contributed to
the overall decrease in operating cash flow provided by the domestic
utility companies and System Energy. Increases in income taxes accrued
resulting from book and tax income timing differences added operating cash
flow in 2001 compared to 2000. Management expects that these timing
differences may continue to increase operating cash flow in future
periods.
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
LIQUIDITY AND CAPITAL RESOURCES
Money pool activity also affected the operating cash flows of the
domestic utility companies and System Energy. The increases (decreases)
in money pool borrowings during 2001 and 2000 are as follows:
Nine Months Ended Nine Months Ended
Company Sept. 30, 2001 Sept. 30, 2000
(In Millions)
Entergy Arkansas $48.2 ($30.5)
Entergy Gulf States - ($36.1)
Entergy Louisiana - ($91.5)
Entergy Mississippi $13.6 ($43.2)
Entergy New Orleans $13.2 ($6.7)
For the lenders to the money pool for the first nine months of 2001,
Entergy Gulf States' money pool associated company receivables increased
$49.3 million, Entergy Louisiana's money pool associated company
receivables decreased $14.1 million, and System Energy's money pool
associated company receivables decreased $8.3 million, in each case for
the nine months ended September 30, 2001. For the nine months ended
September 30, 2000, System Energy's money pool associated company
receivables decreased $144.5 million.
The money pool is an inter-company funding arrangement designed to
reduce the domestic utility companies' and System Energy's dependence on
external short-term borrowings. The money pool provides a means by which,
on a daily basis, the excess funds of Entergy Corporation, the domestic
utility companies, and System Energy may be used by the domestic utility
companies or System Energy to fulfill short-term cash requirements. See
"Capital Resources - Sources of Capital" below for a discussion of the
limitations on these borrowings.
Investing Activities
Net cash used in investing activities increased for the nine months
ended September 30, 2001 compared to the nine months ended September 30,
2000 primarily due to:
o approximately $600 million paid to acquire the Indian Point 2 nuclear
plant in September 2001;
o capital contributions made in the formation of Entergy-Koch,
discussed below in "Uses of Capital - Energy Commodity Services;"
o investments used as collateral for letters of credit by the domestic
non-utility nuclear business, discussed below in "Uses of Capital -
Domestic Non-Utility Nuclear;"
o the maturity of other temporary investments in 2000 and additional
temporary investments made in 2001; and
o proceeds from the sale of the Freestone power project in 2000.
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
LIQUIDITY AND CAPITAL RESOURCES
The following factors partially offset the overall increase in cash
used in investing activities for the same period:
o receipt of approximately $810 million in proceeds from the sale of
the Saltend plant to Calpine Corporation in August 2001;
o decreased construction expenditures due to completion of construction
of the Saltend and Damhead Creek plants;
o decreased payments by EWO for turbines in 2001, discussed below in
"Uses of Capital - Energy Commodity Services;" and
o decreased under-recovery of deferred fuel costs incurred at certain
of the domestic utility companies. Entergy Arkansas, the Texas
portion of Entergy Gulf States, and Entergy Mississippi for 2000 only,
have treated these costs as regulatory investments because these
companies are allowed by their regulatory jurisdictions to recover
the accumulated fuel cost regulatory asset over longer than a twelve
month period. Entergy Mississippi's fuel recovery mechanism changed
effective January 2001, and Entergy Mississippi's fuel cost
under-recoveries incurred after that date will be recoverable over
less than a twelve-month period. The companies will earn a return
on the under-recovered balances.
Financing Activities
Financing activities provided cash during the nine months ended
September 30, 2001 compared with using cash during the nine months ended
September 30, 2000 primarily due to:
o borrowings made during 2001 under the Entergy Corporation credit
facility, including approximately $600 million used in the Indian
Point 2 acquisition;
o decreased repurchases of Entergy Corporation common stock in 2001.
Entergy anticipates limited repurchase activity for the remainder
of 2001;
o redemption of Entergy Gulf States' preference stock in 2000; and
o increased common stock issuances, primarily associated with the
exercise of stock options.
Partially offsetting the increase in cash provided by financing activities
were the following for the same period:
o the approximately $550 million retirement of the Saltend credit
facility in August 2001 when the plant was sold;
o a higher amount of debt issued by the domestic utility companies in
2000 than in 2001; and
o no additional borrowings in 2001 under the Saltend and Damhead Creek
credit facilities due to the completion of construction of the
plants in 2000.
System Energy Proposed Rate Increase Refund
In the third quarter of 2001, FERC's order in System Energy's 1995
rate proceeding became final. As a result, management expects System
Energy to pay a refund of approximately $520 million to four of the
domestic utility companies when FERC accepts System Energy's compliance
filing. System Energy's cash on hand, other temporary investments, money
pool receivables, and its ability to borrow from the money pool are
believed to be sufficient to fund the refund. Management expects System
Energy to pay approximately $187 million to Entergy Arkansas,
approximately $73 million to Entergy Louisiana, approximately $172
million to Entergy Mississippi, and approximately $88 million to Entergy
New Orleans. Up to approximately half of these amounts will in turn be
refunded to customers of these domestic utility companies. In the third
quarter 2001, System Energy recorded an associate company payable for the
refund, and each of the operating companies recorded an associate company
receivable for the refund from System Energy and a liability for the
amount payable to their customers.
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
LIQUIDITY AND CAPITAL RESOURCES
Capital Resources
See "MANAGEMENT'S DISCUSSION AND ANALYSIS - LIQUIDITY AND CAPITAL
RESOURCES - Capital Resources" in the Form 10-K for a discussion of
Entergy's sources of funds and capital requirements. The following are
updates to the Form 10-K.
Sources of Capital
Each of the domestic utility companies issued debt in 2001, with the
exception of Entergy Louisiana. See Note 4 to the financial statements
herein for details regarding long-term debt issued and retired in 2001.
As shown in the earnings ratios in Item 5 of this Form 10-Q, Entergy
New Orleans' earnings for the twelve months ended September 30, 2001 were
not adequate to cover its fixed charges. Under its mortgage covenants,
Entergy New Orleans does not have the capacity to issue new secured debt.
Management did not have plans to issue new secured debt at Entergy New
Orleans through at least 2002, however, and believes that its short-term
and unsecured borrowing capacity will be sufficient for its foreseeable
capital needs. Under restrictions contained in its articles of
incorporation, Entergy New Orleans could issue approximately $20 million
of new unsecured debt as of September 30, 2001.
Short-term borrowings by the domestic utility companies and System
Energy, including borrowings under the money pool, are limited to amounts
authorized by the SEC. See Note 4 to the financial statements in the Form
10-K for further discussion of Entergy's short-term borrowing limits. In
2001, Entergy received SEC approval to increase the authorized limits for
the following companies, as follows:
Company Current Limit
Entergy Mississippi $160 million
Entergy New Orleans $100 million
Other Entergy non-SEC $420 million
registrant subsidiaries
The approval increased the current SEC authorized short-term borrowing
limits for Entergy subsidiaries from $1.343 billion to $1.620 billion.
The SEC authorized limits are effective through November 30, 2001. In
June 2001, Entergy filed with the SEC to extend the authorization period
for the current short-term borrowing limits and the money pool borrowing
arrangement.
The following companies had borrowings outstanding from the money
pool at September 30, 2001:
Outstanding
Company Borrowings
Entergy Arkansas $78.9 million
Entergy Mississippi $46.8 million
Entergy New Orleans $19.0 million
Other Entergy non-SEC $95.7 million
registrant subsidiaries
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
LIQUIDITY AND CAPITAL RESOURCES
Entergy Arkansas, Entergy Louisiana, and Entergy Mississippi each
obtained 364-day credit facilities in 2001 as follows:
Amount of Amount Drawn
Company Date Obtained Facility as of Sept.
30, 2001
Entergy Arkansas January 31, 2001 $63 million -
Entergy Louisiana January 31, 2001 $15 million -
Entergy Mississippi February 2, 2001 $25 million -
Entergy Louisiana's credit facility originally was $30 million, and it was
reduced to its current level in May 2001. The facilities have variable
interest rates and the average commitment fee is 0.13%.
In May 2001, Entergy Corporation amended its 364-day bank credit
facility, increasing the capacity from $500 million to $1.25 billion. In
July 2001, the borrowing capacity on the facility was increased to $1.325
billion, of which $1.05 billion was drawn as of September 30, 2001.
Entergy Corporation has used borrowings from the facility for general
corporate purposes and to make additional investments in competitive
businesses, including the approximately $600 million paid to purchase
Indian Point 2 from Consolidated Edison in September 2001.
Uses of Capital
PUHCA Restrictions on Uses of Capital
Entergy's ability to invest in domestic and foreign generation
businesses is subject to the SEC's regulations under PUHCA. As authorized
by the SEC, Entergy is allowed to invest an amount equal to 100% of its
average consolidated retained earnings in domestic and foreign generation
businesses. As of September 30, 2001, Entergy's investments subject to
this rule totaled $1.36 billion constituting 40.2% of its average
consolidated retained earnings.
See "PUHCA Restrictions on Uses of Capital" in "MANAGEMENT'S
DISCUSSION AND ANALYSIS - LIQUIDITY AND CAPITAL RESOURCES" in the Form 10-
K for a discussion of other PUHCA restrictions affecting Entergy, such as
its capacity to invest in "energy-related" businesses and its ability to
guarantee obligations of its non-utility subsidiaries.
Other Uses of Capital by Entergy Corporation
For the nine months ended September 30, 2001, Entergy Corporation
paid $202 million in cash dividends on its common stock and received
dividend payments and returns of capital totaling $307 million from
subsidiaries. Declarations of dividends on Entergy's common stock are
made at the discretion of the Board. The Board evaluates the level of
Entergy common stock dividends based upon Entergy's earnings, financial
strength, and capital requirements. Restrictions on the ability of
Entergy's subsidiaries to pay dividends are discussed in Note 8 to the
financial statements in the Form 10-K.
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
LIQUIDITY AND CAPITAL RESOURCES
Domestic Non-Utility Nuclear
In connection with the acquisition of FitzPatrick and Indian Point 3,
the installment payments due by Entergy to NYPA must be secured by a
letter of credit from an eligible financial institution. On November 21,
2000, upon closing the acquisition of the NYPA plants, Entergy delivered a
$577 million letter of credit, with NYPA as beneficiary. The letter of
credit was backed by cash collateral, and this cash is reflected in the
consolidated balance sheet at December 31, 2000, as "Special deposits."
In January 2001, Entergy replaced $440 million of the cash collateral with
an Entergy Corporation guarantee. Most of the cash released by this
guarantee was used to fund Entergy's contributions to Entergy-Koch as
discussed below. In June 2001, Entergy Corporation obtained new letters
of credit totaling $577 million, which replaced the letter of credit
initially provided to NYPA. The letters of credit are partially backed by
an Entergy Corporation guarantee and partially backed by $272 million of
cash collateral. The cash collateral is included in "Other" in the Other
Property and Investments section of the consolidated balance sheet at
September 30, 2001.
In August 2001 Entergy's domestic non-utility nuclear business agreed
to purchase the 510 MW Vermont Yankee Nuclear Power Plant in Vernon,
Vermont, from Vermont Yankee Nuclear Power Corporation (VYNPC) for $180
million, to be paid in cash upon closing. Entergy will receive the plant,
nuclear fuel, inventories, and related real estate. The liability to
decommission the plant, as well as related decommissioning trust funds of
approximately $280 million, will also be transferred to Entergy. Under a
10-year power purchase agreement (PPA) executed in conjunction with the
transaction, Entergy will sell 100% of the plant's output up to 510 MW to
VYNPC's current owner-utilities. The PPA includes an adjustment clause
where the prices specified in the PPA will be adjusted downward annually,
beginning in 2006, if power market prices drop below the PPA prices.
Management expects to close the transaction by the spring of 2002, pending
the approvals of the NRC, the Public Service Board of Vermont, and other
regulatory agencies.
Energy Commodity Services
Entergy Wholesale Operations
As discussed in the Form 10-K, Entergy had plans to spend $3.6
billion in the years 2001 through 2003 in its capital investment plan for
EWO's global development business. Investment through September 30, 2001,
however, is behind the amounts included in the plan. Primarily this is
because in many regions of the United States the spark spread, the
difference between the price of electricity and the price of natural gas
at certain conversion efficiencies, has declined significantly since
earlier this year. The decline is adversely impacting the profitability
of power projects selling into power markets on a spot or short-term
basis. EWO is attempting to address this spark spread uncertainty through
long-term power sales and tolling agreements in its project development
efforts. Nevertheless, management can provide no assurance that EWO will
be able to obtain long-term agreements for these projects. An inability
to structure projects to mitigate these risks could result in a reduction
in the capital spending plans.
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
LIQUIDITY AND CAPITAL RESOURCES
Also as discussed in the Form 10-K, the global power development
business obtained contracts in October 1999 to acquire 36 turbines from
General Electric. As noted below, the rights and obligations under the
contracts for 22 of the turbines were sold to a third party in May 2001.
In conjunction with Entergy's obligations related to this sale, Entergy
retained certain rights to reacquire turbines or to cancel the
construction of turbines. Thus far, EWO has placed 17 of the originally
planned 36 turbines at sites that are either operating, under
construction, or sold. In addition, cancellation of four turbines
subject to the May 2001 sale agreement is pending. If EWO were to decide
to cancel the remaining turbines subject to the May 2001 sale agreement,
its exposure at September 30, 2001 would be approximately $250 million.
This exposure, however, does not take into account Entergy's ability to
sell the turbines (subject to certain consent rights of General Electric),
and EWO's ongoing efforts to develop sites for the turbines. EWO will
continue to actively manage its assets as an investment portfolio, and
attempt to maximize flexibility to respond to different market
environments. Active management of the portfolio by EWO will continue to
result in: the sale of projects at various stages in their planning,
development, or operation; the abandonment of projects; or the commercial
operation of projects by EWO.
As part of its turbine acquisition program, an EWO subsidiary (EPDC)
sold its rights and obligations under certain of the turbine acquisition
contracts with General Electric Company to a third party in May 2001. The
rights to 22 turbines were included in the sale. As discussed in the
preceding paragraph, cancellation of four of these turbines is pending,
and three others have been committed to a site under construction. The
sale price was approximately $150 million, which corresponded to the
amount EPDC had invested in the turbines under construction. The
purchaser obtained a revolving financing facility of up to $450 million
for the fabrication and acquisition of turbines. EPDC has certain rights
to reacquire the turbines from the purchaser, whether pursuant to an
interim lease commencing when a turbine is ready for shipment or pursuant
to certain purchase rights. The lease payments and purchase price for
each turbine have been established pursuant to various agreements between
EPDC, the purchaser, and its lenders. If EPDC does not take title to the
turbines prior to certain specified dates, the purchaser has certain
rights to sell the turbines and EPDC may be held liable for specific
defined shortfalls, if any. Certain EPDC obligations under these
agreements will be backed by an Entergy Corporation guarantee.
Entergy-Koch, L.P.
In January 2001, subsidiaries of Entergy and Koch Industries, Inc.
formed a new limited partnership called Entergy-Koch, L.P. Entergy
contributed substantially all of its power marketing and trading business
in the United States and the United Kingdom and made other contributions,
including equity and loans, totaling $414 million. Koch contributed to
the venture its 9,000-mile Koch Gateway Pipeline (which has been renamed
the Gulf South Pipeline), gas storage facilities, including the Bistineau
storage facility near Shreveport, Louisiana, and Koch Energy Trading,
which markets and trades electricity, gas, weather derivatives, and other
energy-related commodities and services.
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Entergy's consolidated earnings applicable to common stock were
$312.5 million and $705.5 million for the three and nine months ended
September 30, 2001, respectively. The changes in earnings applicable to
common stock by operating segments for the three and nine months ended
September 30, 2001, compared to the same periods in 2000, are as follows:
Three Months Ended Nine Months Ended
Operating Segments Increase/(Decrease) Increase/(Decrease)
(In Thousands)
Domestic Utility and System Energy ($60,386) ($34,339)
Domestic Non-Utility Nuclear 28,089 68,888
Energy Commodity Services (primarily EWO and Entergy-Koch) 60,414 67,066
Other, including parent company (15,567) (32,057)
------- -------
Total $12,550 $69,558
======= =======
Increases in earnings per average common share for Entergy:
Basic 4% 15%
Diluted 4% 13%
See Note 6 to the financial statements for additional business segment
information.
The decreased earnings for the domestic utility and System Energy
segment for the three and nine months ended September 30, 2001 were
primarily due to a decrease in net revenues and an increase in interest
expense. The decrease in earnings was partially offset by decreases in
decommissioning expense, other operation and maintenance expenses, and
depreciation and amortization expense, each of which resulted from
entries made after receipt of a final FERC order addressing the 1995
System Energy rate increase filing, as well as net increases in
regulatory credits. See Note 2 to the financial statements herein for
further discussion of the System Energy rate proceeding.
The increased earnings for domestic non-utility nuclear in 2001 were
primarily due to the operation of FitzPatrick and Indian Point 3, each of
which Entergy purchased in November 2000.
The increased earnings in 2001 for energy commodity services were
primarily due to:
o a $69.9 million ($45.4 million net of tax) gain reported in third
quarter revenues due to the sale of EWO's Saltend plant in August 2001;
and
o favorable results from Entergy-Koch. Prior to 2001, revenues and
expenses from the operation of Entergy's power marketing and trading
business were consolidated in Entergy's financial statements. On
January 31, 2001, Entergy contributed substantially all of its power
marketing and trading business to Entergy-Koch. Entergy accounts for
its 50% share in the investment under the equity method of accounting.
Certain terms of the partnership arrangement allocate income from
various sources, and the taxes on that income, on a disproportionate
basis. These disproportionate allocations have been favorable to
Entergy in the aggregate in 2001.
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
The increased earnings for energy commodity services for the three
and nine months ended September 30, 2001 was partially offset by the
following events, which are discussed in more detail below, that occurred
at EWO:
o a loss reserve recorded in connection with the pending cancellation
of four gas turbines previously expected to be operational in 2005;
o more liquidated damages received as compensation for lost operating
margin due to plant construction delays from the Saltend contractor in
2000 than from the Damhead Creek contractor in 2001;
o a gain on the sale of the Freestone project located in Fairfield,
Texas, in June 2000;
o an increase in depreciation expense due to commercial operation of
the Saltend and Damhead Creek plants; and
o an increase in interest expense.
The increased expenses from the commercial operation of Saltend and
Damhead Creek more than offset the operating margin generated by those
plants in 2001.
Entergy's share repurchase program also contributed to the increases
in earnings per share by decreasing the weighted average number of shares
outstanding.
Entergy's income before taxes is discussed according to the operating
segments listed above. "Competitive businesses" operating revenues in the
statements of income include primarily revenues generated by domestic non-
utility nuclear, EWO, and, for 2000 only, power marketing and trading.
Domestic Utility and System Energy
The changes in electric operating revenues for Entergy's domestic
utility companies for the three and nine months ended September 30, 2001
compared to the same periods in 2000 are as follows:
Three Months Ended Nine Months Ended
Description Increase/(Decrease) Increase/(Decrease)
(In Millions)
Base rate changes $2.2 ($21.7)
Rate riders (22.2) (20.9)
Fuel cost recovery (78.9) 763.5
Sales volume/weather (69.4) (26.6)
Other revenue (including unbilled) (224.0) (281.5)
Sales for resale (6.5) 34.3
------- ------
Total ($398.8) $447.1
======= ======
Fuel cost recovery
The domestic utility companies are allowed to recover certain fuel
and purchased power costs through fuel mechanisms included in electric
rates that are recorded as fuel cost recovery revenues. The difference
between revenues collected and current fuel and purchased power costs is
reflected as deferred fuel costs on Entergy's financial statements such
that these costs do not have a material net effect on earnings.
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
The decrease in fuel cost recovery revenue for the three months ended
September 30, 2001 was primarily due to decreased fuel and purchased power
costs recovered through fuel mechanisms at Entergy Louisiana and in the
Louisiana jurisdiction of Entergy Gulf States. The decrease was partially
offset by increased fuel recovery factors at Entergy Arkansas, Entergy
Mississippi, and in the Texas jurisdiction of Entergy Gulf States.
The increase in fuel cost recovery revenue for the nine months ended
September 30, 2001 was primarily due to:
o increased fuel recovery factors at Entergy Arkansas, Entergy Gulf
States in the Texas jurisdiction, and Entergy Mississippi; and
o higher fuel and purchased power costs recovered through fuel
mechanisms at Entergy Gulf States in the Louisiana jurisdiction,
Entergy Louisiana, and Entergy New Orleans due to the increased
market prices of natural gas and purchased power early in 2001.
Corresponding to the decrease in fuel cost recovery revenue for the
three months ended September 30, 2001, fuel and purchased power expenses
related to electric sales decreased approximately $86.0 million primarily
due to:
o a decrease in the market price of natural gas; and
o the receipt in September 2001 of a final FERC order requiring System
Energy to refund a portion of its December 1995 rate increase. The
effect of the order reduced purchased power expenses by $27.9 million
for the portion of the refund related to the Entergy Arkansas and
Entergy Louisiana retained shares of Grand Gulf 1.
An increase of $752.5 million in fuel and purchased power expenses
related to electric sales corresponded to the increase in fuel cost
recovery revenue for the nine months ended September 30, 2001. The
increase was primarily due to an increase in the market prices of natural
gas and purchased power early in 2001.
Other effects on electric operating revenue
Lower electric sales volume reduced revenues for the three and nine
months ended September 30, 2001 due to decreased weather-adjusted usage of
861 GWH and 1,159 GWH, respectively. Each domestic utility company
experienced decreases in weather-adjusted usage. However, the primary
decreases in weather-adjusted usage were from industrial customers at
Entergy Louisiana and Entergy Gulf States. Electric sales vary seasonally
in response to weather and usually peak in the summer. The effect of
milder-than-normal summer weather conditions also caused a decrease in
electric sales in 2001. For the three and nine months ended September 30,
2001, electric sales volume in the domestic utility companies' service
territories decreased 1,250 GWH and 324 GWH, respectively, due to the
impact of weather conditions. The decrease for the nine months ended was
partially offset by an increase in electric sales volume in residential
and commercial sectors at Entergy Arkansas. The number of customers in
the domestic utility companies' service territories increased only
slightly during these periods.
Other revenue decreased for the three and nine months ended September
30, 2001, primarily reflecting the receipt of a final FERC order requiring
System Energy to refund a portion of its December 1995 rate increase,
which increased provisions for rate refunds $93 million at System Energy.
Unbilled revenues decreased for the three and nine months ended September
30, 2001 as a result of decreased fuel prices and less favorable sales
volume in the period included in the unbilled revenue calculation compared
to the calculation in the prior year. Sales for resale increased for the
nine months ended September 30, 2001 due to higher prices of resale
electricity early in 2001.
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Gas operating revenues
Natural gas revenues increased $63.0 million for the nine months
ended September 30, 2001, primarily due to increased market prices for
natural gas early in 2001 and additional sales volume due to the colder-
than-normal winter. The increase in gas revenues was partially offset by
an increase of approximately $54.4 million in gas purchased for resale for
the same period.
Other effects on results
Results for the three and nine months ended September 30, 2001 for
the domestic utility companies and System Energy were also affected by the
following:
o decreases in other operation and maintenance expenses of $15.7
million for the three months ended and $62.7 million for the nine
months ended, which are explained below;
o a decrease in decommissioning expense at System Energy of $31.5
million for both the three and nine months ended resulting from the
final resolution of the FERC order addressing the 1995 rate increase
filing;
o decreases in depreciation and amortization expense at System Energy
of $79.6 million for the three months ended and $78.8 million for the
nine months ended primarily resulting from the final resolution of the
FERC order addressing the 1995 rate increase filing;
o net increases in regulatory credits of $72.4 million for the three
months ended and $48.4 million for the nine months ended, which are
explained below;
o increases in interest expense of $42.8 million for the three months
ended and $66.1 million for the nine months ended, which are explained
below; and
o increases in other income of $9.1 million for the three months ended
and $21.9 million for the nine months ended, primarily from carrying
charges on deferred fuel costs.
The decreases in other operation and maintenance expenses for the
three and nine months ended September 30, 2001 compared to the same
periods in 2000 were primarily due to:
o a decrease in property insurance expense for the three months ended
due to a $5.0 million true-up in September 2000 to modify storm damage
expense included in the annual update of the excess earnings review to a
level negotiated with the APSC;
o a decrease in property insurance expense for the nine months ended
primarily due to a reversal in June 2001, upon recommendation from the
APSC, of $24.5 million of ice storm costs previously charged to expense
in December 2000 (these costs are now reflected as regulatory assets);
o the disposal of low-level radioactive waste in 2000 at Entergy Gulf
States resulting in a $4.0 million decrease for the three months ended;
o decreases in legal expenses of $1.9 million for the three months
ended at Entergy Gulf States and $1.3 million for the three months ended
and $10.5 million for the nine months ended at Entergy Arkansas; and
o decreases in injury and damages claims, plant maintenance expenses,
and vegetation maintenance spending.
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
The net increases in regulatory credits were primarily due to:
o the amount of capacity charges included in purchased power costs for
the summers of 2000 and 2001 that Entergy Gulf States and Entergy
Louisiana deferred and expects to recover in the future; and
o a greater under-recovery of Grand Gulf costs in 2001 at Entergy
Mississippi.
The increases in interest expense were primarily due to:
o the final FERC order addressing the 1995 System Energy rate increase
filing;
o debt issued at Entergy Gulf States in June 2000 and August 2001, at
Entergy Mississippi in February 2000 and January 2001, and at Entergy
New Orleans in July 2000 and February 2001; and
o borrowings under credit facilities during 2001, primarily at Entergy
Arkansas.
Domestic Non-Utility Nuclear
Increases in earnings for the domestic non-utility nuclear business
were primarily due to revenue increases of $146.8 million and
$353.3 million for the three and nine months ended September 30, 2001,
respectively, primarily due to the operation of FitzPatrick and Indian
Point 3, each purchased in November 2000. The following also affected
earnings for domestic non-utility nuclear for the three and nine months
ended September 30, 2001, all of which were primarily caused by the
acquisition of FitzPatrick and Indian Point 3:
o other operation and maintenance expenses increased $58.1 million and
$142.5 million, respectively;
o interest expense, primarily related to debt incurred to purchase
FitzPatrick and Indian Point 3, increased $11.8 million and $46.9
million, respectively;
o fuel expenses increased $15.7 million and $35.6 million,
respectively;
o interest income increased $5.3 million and $22.3 million,
respectively; and
o taxes other than income taxes increased $8.3 million and $20.1
million, respectively.
Energy Commodity Services
Revenues decreased for energy commodity services by $609.7 million
for the three months ended and by $553.3 million for the nine months ended
September 30, 2001, primarily due to the contribution of substantially all
of Entergy's power marketing and trading business to Entergy-Koch in 2001.
Earnings from Entergy-Koch are reported as equity in earnings of
unconsolidated equity affiliates in the financial statements.
The decreases in revenues for the three and nine months ended
September 30, 2001 were partially offset by:
o increased operating revenues for EWO from its investments in Highland
Energy and the Saltend and Damhead Creek plants; and
o a gain reported in third quarter revenues due to the sale of EWO's
Saltend plant in August 2001.
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Operating revenues for EWO increased for the three and nine months
ended September 30, 2001 primarily due to increases of $127.3 million and
$495.3 million, respectively, from EWO's interest in Highland Energy and
increases of $182.1 million and $403.7 million, respectively, from the
Saltend and Damhead Creek plants. Highland Energy was acquired in June
2000 and the Saltend and Damhead Creek plants began commercial operation
in late November 2000 and early 2001, respectively. For the three and
nine months ended September 30, 2001, the increase in revenues for EWO is
largely offset by increases in fuel and purchased power expenses of
$207.2 million and $721.0 million, respectively, and increases in other
operation and maintenance expenses of $7.1 million and $47.5 million,
respectively.
EWO sold the Saltend plant in August 2001, and revenues in the third
quarter include the $69.9 million ($45.4 million net of tax) gain on the
sale. EWO actively manages its assets as an investment portfolio, and
attempts to maximize flexibility to respond to different market
environments. Active management of the portfolio by EWO will continue to
result in: the sale of projects at various stages in their planning,
development, or operation; the abandonment of projects; or the commercial
operation of projects by EWO.
As previously discussed, substantially all of Entergy's power
marketing and trading business was contributed to Entergy-Koch in 2001,
and earnings from this joint venture are reported as equity in earnings
of unconsolidated equity affiliates in the financial statements. As a
result, for the three and nine months ended September 30, 2001, revenues
reported for Entergy-Koch/Power Marketing and Trading were lower by
$914.5 million and $1,588.9 million, respectively, and purchased power
expenses were lower by $903.5 million and $1,422.5 million, respectively.
The net income effect of the lower revenues in these periods, however,
was more than offset by the equity in earnings from Entergy's interest in
Entergy-Koch. Earnings increased in 2001 as a result of increased
electricity and gas trading volumes as well as a broader range of
commodity sources and options provided to customers by the joint venture
in 2001. Certain terms of the partnership arrangement allocate income
from various sources, and the taxes on that income, on a disproportionate
basis. These disproportionate allocations have been favorable to Entergy
in the aggregate in 2001.
The increase in earnings for energy commodity services for the three
months ended September 30, 2001 was primarily due to the sale of EWO's
Saltend plant and favorable results from Entergy-Koch as mentioned above.
The increase in earnings was partially offset by increased interest
expense of $14.2 million and increased depreciation expense of $8.3
million, respectively, primarily due to interest and depreciation related
to commencement of commercial operation of EWO's Saltend and Damhead Creek
plants.
The increase in earnings for energy commodity services for the nine
months ended September 30, 2001 was primarily due to:
o the gain on the sale of EWO's Saltend plant as mentioned above;
o the favorable results from Entergy-Koch mentioned above;
o liquidated damages of $13.9 million ($9.7 million net of tax)
received in 2001 from the Damhead Creek construction contractor as
compensation for lost operating margin from the plant due to
construction delays; and
o an $11.0 million ($7.2 million net of tax) gain on the sale of a
permitted site in Desoto County, Florida, in May 2001.
ENTERGY CORPORATION AND SUBSIDIARIES
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Partially offsetting the increase in earnings for energy commodity
services for the nine months September 30, 2001 were the following:
o an $18.0 million ($11.7 million net of tax) loss reserve recorded
primarily because of the pending cancellation of four gas turbines
scheduled for delivery in 2005;
o liquidated damages of $55.1 million ($38.6 million net of tax)
received in 2000 from the Saltend contractor as compensation for lost
operating margin from the plant due to construction delays;
o a $20.5 million ($13.3 million net of tax) gain on the sale of the
Freestone project located in Fairfield, Texas, in June 2000;
o increased depreciation expense of $25.2 million in 2001 primarily due
to the commencement of the commercial operation of the Saltend and
Damhead Creek plants; and
o increased interest expense of $53.5 million in 2001 primarily because
the interest related to the Saltend and Damhead Creek plants was
capitalized until those plants commenced commercial operation.
Other
Earnings from Other decreased primarily due to $21.8 million ($13.4
million net of tax) of merger-related expenses incurred by Entergy
Corporation in the first quarter of 2001 and decreased interest income of
$10.8 million and $22.1 million for the three and nine months ended
September 30, 2001, respectively.
Income taxes
The effective income tax rates for the three months ended September
30, 2001 and 2000 were 36.9% and 40.4%, respectively. The effective
income tax rates for the nine months ended September 30, 2001 and 2000
were 38.8% and 40.0%, respectively. The decrease in the effective tax
rates for the three and nine months ended was primarily because of the
effects of the final FERC order addressing System Energy's 1995 rate
proceeding.
ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
For the Three and Nine Months Ended September 30, 2001 and 2000
(Unaudited)
Three Months Ended Nine Months Ended
2001 2000 2001 2000
(In Thousands, Except Share Data)
OPERATING REVENUES
Domestic electric $1,986,338 $2,385,087 $5,849,720 $5,402,657
Natural gas 18,212 21,815 159,144 96,107
Competitive businesses 571,186 1,024,653 1,714,574 1,882,071
---------- ---------- ---------- ----------
TOTAL 2,575,736 3,431,555 7,723,438 7,380,835
---------- ---------- ---------- ----------
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale 925,452 794,782 3,076,932 1,756,972
Purchased power 279,060 1,158,145 888,835 2,030,210
Nuclear refueling outage expenses 24,284 18,439 64,567 53,625
Other operation and maintenance 550,339 504,379 1,469,408 1,332,012
Decommissioning (22,553) 11,505 (4,749) 28,611
Taxes other than income taxes 103,593 103,188 295,717 266,346
Depreciation and amortization 127,650 188,967 514,099 545,991
Other regulatory charges (credits) - net (24,621) 47,816 (21,075) 27,311
Amortization of rate deferrals 6,029 10,497 15,181 25,776
---------- ---------- ---------- ----------
TOTAL 1,969,233 2,837,718 6,298,915 6,066,854
---------- ---------- ---------- ----------
OPERATING INCOME 606,503 593,837 1,424,523 1,313,981
---------- ---------- ---------- ----------
OTHER INCOME
Allowance for equity funds used during construction 7,672 9,163 19,259 24,898
Gain (loss) on sale of assets - net 2,066 (284) 14,414 21,291
Equity in earnings of unconsolidated equity affiliates 58,414 - 153,957 -
Miscellaneous - net 37,643 53,873 139,862 156,505
---------- ---------- ---------- ----------
TOTAL 105,795 62,752 327,492 202,694
---------- ---------- ---------- ----------
INTEREST AND OTHER CHARGES
Interest on long-term debt 126,670 121,464 386,373 353,585
Other interest - net 84,452 22,576 183,752 66,227
Distributions on preferred securities of subsidiary 4,709 4,709 14,128 14,128
Allowance for borrowed funds used during construction (6,287) (6,776) (15,718) (18,753)
---------- ---------- ---------- ----------
TOTAL 209,544 141,973 568,535 415,187
---------- ---------- ---------- ----------
INCOME BEFORE INCOME TAXES 502,754 514,616 1,183,480 1,101,488
Income taxes 185,300 207,927 459,573 440,616
---------- ---------- ---------- ----------
CONSOLIDATED NET INCOME 317,454 306,689 723,907 660,872
Preferred dividend requirements and other 4,970 6,755 18,363 24,886
---------- ---------- ---------- ----------
EARNINGS APPLICABLE TO
COMMON STOCK $312,484 $299,934 $705,544 $635,986
========== ========== ========== ==========
Earnings per average common share:
Basic $1.41 $1.35 $3.19 $2.78
Diluted $1.39 $1.34 $3.14 $2.77
Dividends declared per common share $0.32 $0.30 $0.95 $0.90
Average number of common shares outstanding:
Basic 221,675,578 222,159,091 220,908,546 228,930,171
Diluted 224,830,056 224,352,165 224,780,449 230,034,859
See Notes to Financial Statements.
ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2001 and 2000
(Unaudited)
2001 2000
(In Thousands)
OPERATING ACTIVITIES
Consolidated net income $723,907 $660,872
Noncash items included in net income:
Amortization of rate deferrals 15,181 25,776
Reserve for regulatory adjustments (357,880) (36,756)
Other regulatory charges (credits) - net (21,075) 27,311
Depreciation, amortization, and decommissioning 509,350 574,602
Deferred income taxes and investment tax credits (53,037) (8,074)
Allowance for equity funds used during construction (19,259) (24,898)
Gain on sale of assets - net (14,414) (21,291)
Equity in earnings of unconsolidated equity affiliates (153,957) -
Changes in working capital:
Receivables 33,355 (538,840)
Fuel inventory (24,898) (26,660)
Accounts payable (467,749) 270,152
Taxes accrued 457,995 331,509
Interest accrued 10,289 24,319
Deferred fuel 367,105 (33,619)
Other working capital accounts (11,291) 85,145
Provision for estimated losses and reserves (10,706) (8,844)
Changes in other regulatory assets 61,583 (131)
Other 184,257 138,580
---------- ----------
Net cash flow provided by operating activities 1,228,756 1,439,153
---------- ----------
INVESTING ACTIVITIES
Construction/capital expenditures (939,662) (1,112,075)
Allowance for equity funds used during construction 19,259 24,898
Nuclear fuel purchases (119,277) (100,367)
Proceeds from sale/leaseback of nuclear fuel 60,679 96,412
Proceeds from sale of businesses 805,945 61,519
Changes in other nonregulated/nonutility properties - net (565,333) (184,339)
Increase in other investments (632,548) -
Changes in other temporary investments - net (250,600) 299,455
Decommissioning trust contributions and realized change in trust assets (79,047) (44,799)
Other regulatory investments (36,461) (264,721)
Other (12,200) 5,149
---------- ----------
Net cash flow used in investing activities (1,749,245) (1,218,868)
---------- ----------
Statement continued on following page.
ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2001 and 2000
(Unaudited)
2001 2000
(In Thousands)
FINANCING ACTIVITIES
Proceeds from the issuance of:
Long-term debt $489,295 $934,479
Common stock 62,335 14,810
Retirement of long-term debt (877,088) (145,011)
Repurchase of common stock (36,895) (500,644)
Redemption of preferred and preference stock (39,574) (156,260)
Changes in short-term borrowings - net 662,997 (120,000)
Dividends paid:
Common stock (202,112) (204,660)
Preferred stock (20,281) (23,487)
---------- ----------
Net cash flow provided by (used in) financing activities 38,677 (200,773)
---------- ----------
Effect of exchange rates on cash and cash equivalents 664 (142)
---------- ----------
Net increase (decrease) in cash and cash equivalents (481,148) 19,370
Cash and cash equivalents at beginning of period 1,382,424 1,213,719
---------- ----------
Cash and cash equivalents at end of period $901,276 $1,233,089
========== ==========
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized $570,846 $382,313
Income taxes $6,872 $146,664
Noncash investing and financing activities:
Change in unrealized appreciation/(depreciation) of
decommissioning trust assets ($38,718) $38,837
Net assets contributed to Entergy-Koch $80,145 -
Decommissioning trust fund acquired in Indian Point 2 acquisition $430,000 -
See Notes to Financial Statements.
ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2001 and December 31, 2000
(Unaudited)
2001 2000
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash $224,293 $157,550
Temporary cash investments - at cost,
which approximates market 675,790 640,038
Special deposits 1,193 584,836
----------- -----------
Total cash and cash equivalents 901,276 1,382,424
----------- -----------
Other temporary investments 250,600 -
Notes receivable 3,000 3,608
Accounts receivable:
Customer 572,807 497,821
Allowance for doubtful accounts (9,947) (9,947)
Other 189,988 395,518
Accrued unbilled revenues 368,903 415,409
----------- -----------
Total receivables 1,121,751 1,298,801
----------- -----------
Deferred fuel costs 310,880 568,331
Fuel inventory - at average cost 118,976 93,679
Materials and supplies - at average cost 457,539 425,357
Rate deferrals 1,402 16,581
Deferred nuclear refueling outage costs 101,227 46,544
Prepayments and other 90,060 122,690
----------- -----------
TOTAL 3,356,711 3,958,015
----------- -----------
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity 641,466 214
Decommissioning trust funds 1,781,661 1,315,857
Non-utility property - at cost (less accumulated depreciation) 292,857 262,952
Non-regulated investments 139,198 189,154
Other - at cost (less accumulated depreciation) 354,063 27,036
----------- -----------
TOTAL 3,209,245 1,795,213
----------- -----------
PROPERTY, PLANT AND EQUIPMENT
Electric 26,012,486 25,137,562
Plant acquisition adjustment 378,465 390,664
Property under capital lease 758,458 831,822
Natural gas 199,928 190,989
Construction work in progress 897,709 936,785
Nuclear fuel under capital lease 235,199 277,673
Nuclear fuel 243,671 157,603
----------- -----------
TOTAL PROPERTY, PLANT AND EQUIPMENT 28,725,916 27,923,098
Less - accumulated depreciation and amortization 11,787,620 11,477,352
----------- -----------
PROPERTY, PLANT AND EQUIPMENT - NET 16,938,296 16,445,746
----------- -----------
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
SFAS 109 regulatory asset - net 1,001,884 980,266
Unamortized loss on reacquired debt 170,799 183,627
Deferred fuel costs 22,468 95,661
Other regulatory assets 709,312 792,515
Long-term receivables 28,870 29,575
Other 744,049 1,171,278
----------- -----------
TOTAL 2,677,382 3,252,922
----------- -----------
TOTAL ASSETS $26,181,634 $25,451,896
=========== ===========
See Notes to Financial Statements.
ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND SHAREHOLDERS' EQUITY
September 30, 2001 and December 31, 2000
(Unaudited)
2001 2000
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt $601,937 $464,215
Notes payable 1,051,018 388,023
Accounts payable 594,320 1,204,227
Customer deposits 183,808 172,169
Taxes accrued 924,621 451,811
Accumulated deferred income taxes 68,248 225,649
Nuclear refueling outage costs 16,163 10,209
Interest accrued 185,440 172,033
Obligations under capital leases 154,713 156,907
Other 325,092 192,908
----------- -----------
TOTAL 4,105,360 3,438,151
----------- -----------
DEFERRED CREDITS AND OTHER LIABILITIES
Accumulated deferred income taxes 3,398,899 3,249,083
Accumulated deferred investment tax credits 476,895 494,315
Obligations under capital leases 150,681 201,873
FERC settlement - refund obligation 25,234 30,745
Other regulatory liabilities 139,095 104,841
Decommissioning 1,170,657 749,708
Transition to competition 222,021 191,934
Regulatory reserves 38,909 396,789
Accumulated provisions 372,537 390,116
Other 760,975 853,137
----------- -----------
TOTAL 6,755,903 6,662,541
----------- -----------
Long-term debt 7,237,613 7,732,093
Preferred stock with sinking fund 26,185 65,758
Company-obligated mandatorily redeemable
preferred securities of subsidiary trusts holding
solely junior subordinated deferrable debentures 215,000 215,000
SHAREHOLDERS' EQUITY
Preferred stock without sinking fund 334,687 334,688
Common stock, $.01 par value, authorized 500,000,000
shares; issued 248,174,087 shares in 2001 and
248,094,614 shares in 2000 2,482 2,481
Paid-in capital 4,662,762 4,660,483
Retained earnings 3,688,624 3,190,639
Accumulated other comprehensive loss (96,913) (75,033)
Less - treasury stock, at cost (27,161,334 shares in 2001 and
28,490,031 shares in 2000) 750,069 774,905
----------- -----------
TOTAL 7,841,573 7,338,353
----------- -----------
Commitments and Contingencies (Notes 1 and 2)
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $26,181,634 $25,451,896
=========== ===========
See Notes to Financial Statements.
ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF RETAINED EARNINGS, COMPREHENSIVE INCOME,
AND PAID-IN CAPITAL
For the Three and Nine Months Ended September 30, 2001 and 2000
(Unaudited)
Three Months Ended
2001 2000
(In Thousands)
RETAINED EARNINGS
Retained Earnings - Beginning of period $3,445,141 $2,982,495
Add - Earnings applicable to common stock 312,484 $312,484 299,934 $299,934
Deduct:
Dividends declared on common stock 69,841 66,835
Capital stock and other expenses (840) (801)
---------- ----------
Total 69,001 66,034
---------- ----------
Retained Earnings - End of period $3,688,624 $3,216,395
========== ==========
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS):
Balance at beginning of period ($100,433) ($76,086)
Net derivative instrument fair value changes
arising during the period (1,475) (1,475) - -
Foreign currency translation adjustments 7,848 7,848 (1,270) (1,270)
Net unrealized investment gains (losses) (2,853) (2,853) 12,863 12,863
---------- -------- ---------- --------
Balance at end of period:
Accumulated derivative instrument fair value changes (23,343) -
Other accumulated comprehensive income (loss) items (73,570) (64,493)
---------- ----------
Total ($96,913) ($64,493)
========== -------- ========== --------
Comprehensive Income $316,004 $311,527
======== ========
PAID-IN CAPITAL
Paid-in Capital - Beginning of period $4,661,334 $4,636,407
Add: Common stock issuances related to stock plans 1,428 404
---------- ----------
Paid-in Capital - End of period $4,662,762 $4,636,811
========== ==========
Nine Months Ended
2001 2000
(In Thousands)
RETAINED EARNINGS
Retained Earnings - Beginning of period $3,190,639 $2,786,467
Add - Earnings applicable to common stock 705,544 $705,544 635,986 $635,986
Deduct:
Dividends declared on common stock 208,766 206,886
Capital stock and other expenses (1,207) (828)
---------- ----------
Total 207,559 206,058
---------- ----------
Retained Earnings - End of period $3,688,624 $3,216,395
========== ==========
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS):
Balance at beginning of period ($75,033) ($73,805)
Cumulative effect to January 1, 2001 of accounting
change regarding fair value of derivative instruments (29,067) - - -
Net derivative instrument fair value changes
arising during the period 5,724 5,724 - -
Foreign currency translation adjustments 4,213 4,213 (2,299) (2,299)
Net unrealized investment gains (losses) (2,750) (2,750) 11,611 11,611
---------- -------- ---------- --------
Balance at end of period:
Accumulated derivative instrument fair value changes (23,343) -
Other accumulated comprehensive income (loss) items (73,570) (64,493)
---------- ----------
Total ($96,913) ($64,493)
========== -------- ========== --------
Comprehensive Income $712,731 $645,298
======== ========
PAID-IN CAPITAL
Paid-in Capital - Beginning of period $4,660,483 $4,636,163
Add: Common stock issuances related to stock plans 2,279 648
---------- ----------
Paid-in Capital - End of period $4,662,762 $4,636,811
========== ==========
See Notes to Financial Statements.
ENTERGY CORPORATION AND SUBSIDIARIES
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2001 and 2000
(Unaudited)
Three Months Ended Increase/
Description 2001 2000 (Decrease) %
(In Millions)
Domestic Electric Operating Revenues:
Residential $874.8 $940.6 ($65.8) (7)
Commercial 529.9 518.0 11.9 2
Industrial 532.2 598.9 (66.7) (11)
Governmental 55.5 54.4 1.1 2
-------- -------- -------
Total retail 1,992.4 2,111.9 (119.5) (6)
Sales for resale 108.9 115.4 (6.5) (6)
Other (115.0) 157.8 (272.8) (173)
-------- -------- -------
Total $1,986.3 $2,385.1 ($398.8) (17)
======== ======== =======
Billed Electric Energy
Sales (GWH):
Residential 10,502 11,573 (1,071) (9)
Commercial 7,351 7,578 (227) (3)
Industrial 10,457 11,248 (791) (7)
Governmental 722 744 (22) (3)
-------- -------- -------
Total retail 29,032 31,143 (2,111) (7)
Sales for resale 2,373 2,290 83 4
-------- -------- -------
Total 31,405 33,433 (2,028) (6)
======== ======== =======
Nine Months Ended Increase/
Description 2001 2000 (Decrease) %
(In Millions)
Domestic Electric Operating Revenues:
Residential $2,127.0 $1,933.7 $193.3 10
Commercial 1,462.8 1,252.5 210.3 17
Industrial 1,838.7 1,549.4 289.3 19
Governmental 162.7 134.5 28.2 21
-------- -------- -------
Total retail 5,591.2 4,870.1 721.1 15
Sales for resale 325.8 291.5 34.3 12
Other (67.3) 241.0 (308.3) (128)
-------- -------- -------
Total $5,849.7 $5,402.6 $447.1 8
======== ======== =======
Billed Electric Energy
Sales (GWH):
Residential 24,771 24,943 (172) (1)
Commercial 18,834 18,738 96 1
Industrial 31,478 32,886 (1,408) (4)
Governmental 1,967 1,966 1 -
-------- -------- -------
Total retail 77,050 78,533 (1,483) (2)
Sales for resale 7,004 6,880 124 2
-------- -------- -------
Total 84,054 85,413 (1,359) (2)
======== ======== =======
ENTERGY ARKANSAS, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Net Income
Net income increased for the three months ended September 30, 2001
compared to the three months ended September 30, 2000 primarily due to
receipt of a final FERC order that will result in a refund from System
Energy. The accounting entries necessary to record the effects of the
order reduced purchased power expenses. Decreased other regulatory
charges and decreased other operation and maintenance expenses also
increased net income. The increase was partially offset by increased
interest expense. See Note 2 to the financial statements for further
discussion of System Energy's rate proceeding.
Net income increased for the nine months ended September 30, 2001
compared to the nine months ended September 30, 2000 primarily due to the
effect of the final FERC order in the System Energy rate proceeding and
decreased other operation and maintenance expenses, which includes the
reversal of Arkansas ice storm costs discussed below. The increase was
partially offset by increased depreciation and amortization expenses,
increased other regulatory charges, and increased interest expense.
Revenues and Sales
The changes in electric operating revenues for the three and nine
months ended September 30, 2001 are as follows:
Three Months Ended Nine Months Ended
Description Increase/(Decrease) Increase/(Decrease)
(In Millions)
Base rate changes $4.4 ($6.1)
Rate riders (12.6) (8.4)
Fuel cost recovery 22.9 65.3
Sales volume/weather (9.1) 17.1
Other revenue (including unbilled) (7.8) (15.9)
Sales for resale (4.4) (6.4)
----- -----
Total ($6.6) $45.6
===== =====
Base rate changes
Base rate changes increased revenues for the three months ended
September 30, 2001 primarily due to higher prices for industrial and
commercial customers. The increase in rates is offset by lower revenues
from decreased usage from those customers as discussed below.
Base rate changes decreased revenues for the nine months ended
September 30, 2001 primarily due to the effect of block rates for
residential customers. The decrease in rates is offset by increased
revenues from favorable volume and weather from those customers as
discussed below. The decrease in base rate changes is partially offset by
higher prices for industrial customers due to decreased usage.
Rate riders
Rate rider revenues have no material effect on net income because
specific incurred expenses offset them.
ENTERGY ARKANSAS, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Rate rider revenues decreased for the three months ended September
30, 2001 as a result of a decrease in the Grand Gulf rate rider effective
July 2001. The Grand Gulf rate rider allows Entergy Arkansas to recover
its recoverable share of operating costs for Grand Gulf 1.
Rate rider revenues decreased for the nine months ended September 30,
2001 primarily as a result of the cessation of the ANO Decommissioning
rate rider for the calendar year 2001. In October 2000, the APSC
concluded that funds previously collected, together with future earnings
on those funds, will be sufficient to decommission ANO 1 and 2. Further
details of this decision can be found in Note 2 to the financial
statements in the Form 10-K.
Fuel cost recovery
Entergy Arkansas is allowed to recover certain fuel and purchased
power costs through fuel mechanisms included in electric rates that are
recorded as fuel cost recovery revenues. The difference between revenues
collected and current fuel and purchased power costs is reflected as
deferred fuel costs on Entergy Arkansas' financial statements such that
these costs generally have no net effect on earnings.
Fuel cost recovery revenue increased for the three months ended
September 30, 2001 primarily due to an increase in the energy cost rate,
which became effective in April 2001. The increase in the energy cost
rate allows Entergy Arkansas to recover previously under-recovered fuel
expenses.
Fuel cost recovery revenue increased for the nine months ended
September 30, 2001 primarily due to increases in the energy cost rate that
became effective in April 2000 and April 2001.
Sales volume/weather
Lower electric sales volume reduced revenues for the three months
ended September 30, 2001 due to decreased usage of 97 GWH in the
industrial sector, partially offset by increased weather-adjusted usage of
47 GWH in the residential and commercial sectors. Electric sales vary
seasonally in response to weather and usually peak in the summer.
Unfavorable weather also decreased electric sales for the three months
ended September 30, 2001. The effect of milder-than-normal summer weather
offset the weather-adjusted usage increase in the residential and
commercial sectors with a decrease in electric sales volume of 146 GWH.
Higher electric sales volume increased revenues for the nine months
ended September 30, 2001 due to increased weather-adjusted usage of 235
GWH in the residential and commercial sectors. Electric sales vary
seasonally in response to weather and usually peak in the summer.
Favorable weather also increased electric sales. The effect of colder-
than-normal winter weather in the first quarter of 2001 contributed 177
GWH to the increase in electric sales volume in the residential and
commercial sectors.
Other revenue (including unbilled)
Unbilled revenue decreased for the three months ended September 30,
2001 primarily due to the effect of less favorable weather on the period
included in the September 2001 unbilled revenue calculation compared to
the calculation in September 2000.
Unbilled revenue decreased for the nine months ended September 30,
2001 primarily due to the effect of less favorable weather on the period
included in the September 2001 unbilled revenue calculation compared to
the calculation in the prior year.
ENTERGY ARKANSAS, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Sales for resale
Sales for resale decreased for the three months ended September 30,
2001 primarily due to a decrease in sales volume to adjoining utility
systems as a result of decreased generation, coupled with a decrease in
the average market price of energy. The decrease was partially offset by
an increase in sales volume to affiliated companies.
Sales for resale decreased for the nine months ended September 30,
2001 primarily due to a decrease in sales volume to affiliated companies
and adjoining utility systems as a result of decreased generation. The
decrease was partially offset by an increase in sales volume to municipal
and co-operative customers coupled with an increase in the average market
price of energy early in 2001.
Expenses
Fuel and purchased power
Fuel and purchased power expenses decreased for the three months
ended September 30, 2001 primarily due to receipt of a final FERC order
requiring System Energy to refund a portion of its requested December 1995
rate increase. The effect of the order reduced purchased power expenses
at Entergy Arkansas by $61.5 million. A decrease in the market price of
natural gas also contributed to the decrease in fuel and purchased power
expenses.
Other operation and maintenance
Other operation and maintenance expenses decreased for the three
months ended September 30, 2001 primarily due to:
o a decrease in property insurance expense due to a $5 million true-up
in September 2000 to modify storm damage expense included in the annual
update of the excess earnings review to a level negotiated with the
APSC; and
o a decrease in outside service expense of $1.3 million due to lower
legal expenses.
Other operation and maintenance expenses decreased for the nine
months ended September 30, 2001 primarily due to:
o a decrease in property insurance expense of $24.5 million due to a
reversal in June 2001, upon recommendation from the APSC, of ice storm
costs previously charged to expense in December 2000 (these costs are
now reflected as regulatory assets on Entergy Arkansas' balance sheet);
o a decrease in outside service expense of $10.5 million due to
decreased transition to competition support costs, lower legal expenses,
and decreased information technology maintenance costs; and
o a decrease in overhead line maintenance expense of $9.6 million
primarily due to decreased vegetation maintenance spending.
ENTERGY ARKANSAS, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Depreciation and amortization
Depreciation and amortization expenses increased for the three and
nine months ended September 30, 2001 primarily due to net capital
additions, most notably the ANO 2 replacement steam generators placed in
service in late 2000.
Other regulatory charges (credits)
Other regulatory charges decreased for the three months ended
September 30, 2001 primarily due to a lower adjustment to the transition
cost account made in 2001 as a result of the 2000 excess earnings review,
compared to the adjustment made in September 2000. The transition cost
account is further discussed in Note 2 to the financial statements.
Other regulatory charges increased for the nine months ended
September 30, 2001 primarily due to an increase in the Grand Gulf 1 rider,
which allows for increased recovery of Grand Gulf 1 costs effective
January 2001.
Other
Other income
Other income decreased for the three and nine months ended September
30, 2001 primarily due to a decrease in the allowance for equity funds
used during construction due to a lower construction work in progress
balance during 2001 compared to the same period in 2000. The construction
balance was lower because the ANO 2 replacement steam generators were
placed in service in late 2000. The decrease for the nine months ended
was partially offset by increased interest income recorded on the deferred
fuel balance.
Interest and other charges
Interest and other charges increased for the three and nine months
ended September 30, 2001 due to:
o interest expense on intercompany money pool borrowings;
o interest expense on a $63 million credit facility obtained in January
2001; and
o a decrease in the allowance for borrowed funds used during
construction because of the lower construction work in progress balance
during 2001.
Income taxes
The effective income tax rates for the three months ended September
30, 2001 and 2000 were 40.9% and 43.2%, respectively. The effective income
tax rates for the nine months ended September 30, 2001 and 2000 were 41.1%
and 41.0%, respectively. The decrease in the effective tax rate for the
three months ended was primarily due to a decrease in flow-through items
and permanent tax differences.
ENTERGY ARKANSAS, INC.
INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2001 and 2000
(Unaudited)
Three Months Ended Nine Months Ended
2001 2000 2001 2000
(In Thousands) (In Thousands)
OPERATING REVENUES
Domestic electric $541,556 $548,156 $1,388,463 $1,342,856
-------- -------- ---------- ----------
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale 120,003 74,804 298,165 224,660
Purchased power 76,528 179,587 321,038 398,547
Nuclear refueling outage expenses 7,079 6,439 21,616 19,317
Other operation and maintenance 113,089 119,822 249,913 295,330
Decommissioning 18 2,595 15 1,882
Taxes other than income taxes 8,259 10,664 25,687 28,359
Depreciation and amortization 45,245 42,539 131,268 125,535
Other regulatory charges (credits) - net 7,797 17,789 1,458 (4,381)
-------- -------- ---------- ----------
TOTAL 378,018 454,239 1,049,160 1,089,249
-------- -------- ---------- ----------
OPERATING INCOME 163,538 93,917 339,303 253,607
-------- -------- ---------- ----------
OTHER INCOME
Allowance for equity funds used during construction 1,858 4,416 4,497 11,836
Miscellaneous - net 457 963 5,240 3,201
-------- -------- ---------- ----------
TOTAL 2,315 5,379 9,737 15,037
-------- -------- ---------- ----------
INTEREST AND OTHER CHARGES
Interest on long-term debt 23,171 21,611 67,475 65,745
Other interest - net 3,239 1,915 11,744 6,323
Distributions on preferred securities of subsidiary 1,275 1,275 3,825 3,825
Allowance for borrowed funds used during construction (1,187) (2,888) (2,902) (7,704)
-------- -------- ---------- ----------
TOTAL 26,498 21,913 80,142 68,189
-------- -------- ---------- ----------
INCOME BEFORE INCOME TAXES 139,355 77,383 268,898 200,455
Income taxes 56,954 33,461 110,481 82,242
-------- -------- ---------- ----------
NET INCOME 82,401 43,922 158,417 118,213
Preferred dividend requirements and other 1,912 1,944 5,800 5,832
-------- -------- ---------- ----------
EARNINGS APPLICABLE TO
COMMON STOCK $80,489 $41,978 $152,617 $112,381
======== ======== ========== ==========
See Notes to Financial Statements.
ENTERGY ARKANSAS, INC.
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2001 and 2000
(Unaudited)
2001 2000
(In Thousands)
OPERATING ACTIVITIES
Net income $158,417 $118,213
Noncash items included in net income:
Other regulatory charges (credits) - net 1,458 (4,381)
Depreciation, amortization, and decommissioning 131,283 127,417
Deferred income taxes and investment tax credits (50,323) (3,908)
Allowance for equity funds used during construction (4,497) (11,836)
Changes in working capital:
Receivables (218,974) (61,827)
Fuel inventory (8,605) (5,752)
Accounts payable (111,262) (25,791)
Taxes accrued 151,757 32,794
Interest accrued (11,228) 3,592
Deferred fuel costs 66,973 27,682
Other working capital accounts 62,753 24,602
Provision for estimated losses and reserves (4,536) (396)
Changes in other regulatory assets (57,723) (4,760)
Other 80,979 46,049
-------- --------
Net cash flow provided by operating activities 186,472 261,698
-------- --------
INVESTING ACTIVITIES
Construction expenditures (189,883) (250,643)
Allowance for equity funds used during construction 4,497 11,836
Nuclear fuel purchases (19,103) (32,938)
Proceeds from sale/leaseback of nuclear fuel 19,103 32,938
Decommissioning trust contributions and realized
change in trust assets (6,569) (10,367)
Other regulatory investments (13,834) (59,354)
-------- --------
Net cash flow used in investing activities (205,789) (308,528)
-------- --------
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt 98,919 99,389
Dividends paid:
Common stock (59,100) (44,600)
Preferred stock (5,832) (3,803)
-------- --------
Net cash flow provided by financing activities 33,987 50,986
-------- --------
Net increase in cash and cash equivalents 14,670 4,156
Cash and cash equivalents at beginning of period 7,838 6,862
-------- --------
Cash and cash equivalents at end of period $22,508 $11,018
======== ========
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid/(received) during the period for:
Interest - net of amount capitalized $90,297 $63,290
Income taxes ($3) $46,455
Noncash investing and financing activities:
Change in unrealized appreciation/(depreciation) of
decommissioning trust assets ($17,087) $13,953
See Notes to Financial Statements.
ENTERGY ARKANSAS, INC.
BALANCE SHEETS
ASSETS
September 30, 2001 and December 31, 2000
(Unaudited)
2001 2000
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents $22,508 $7,838
Accounts receivable:
Customer 131,333 98,550
Allowance for doubtful accounts (1,667) (1,667)
Associated companies 222,991 22,286
Other 13,498 26,221
Accrued unbilled revenues 64,096 65,887
---------- ----------
Total accounts receivable 430,251 211,277
---------- ----------
Deferred fuel costs 49,831 102,970
Accumulated deferred income taxes 3,292 -
Fuel inventory - at average cost 18,414 9,809
Materials and supplies - at average cost 74,796 80,682
Deferred nuclear refueling outage costs 21,587 23,541
Prepayments and other 8,461 5,540
---------- ----------
TOTAL 629,140 441,657
---------- ----------
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity 11,217 11,217
Decommissioning trust funds 345,334 355,852
Non-utility property - at cost (less accumulated depreciation) 1,466 1,469
Other - at cost (less accumulated depreciation) 2,976 3,032
---------- ----------
TOTAL 360,993 371,570
---------- ----------
UTILITY PLANT
Electric 5,345,434 5,274,066
Property under capital lease 38,609 40,289
Construction work in progress 170,606 87,389
Nuclear fuel under capital lease 78,282 107,023
Nuclear fuel 9,138 6,720
---------- ----------
TOTAL UTILITY PLANT 5,642,069 5,515,487
Less - accumulated depreciation and amortization 2,616,432 2,534,463
---------- ----------
UTILITY PLANT - NET 3,025,637 2,981,024
---------- ----------
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
SFAS 109 regulatory asset - net 174,853 162,952
Unamortized loss on reacquired debt 41,703 44,428
Other regulatory assets 267,627 221,805
Other 8,686 4,775
---------- ----------
TOTAL 492,869 433,960
---------- ----------
TOTAL ASSETS $4,508,639 $4,228,211
========== ==========
See Notes to Financial Statements.
ENTERGY ARKANSAS, INC.
BALANCE SHEETS
LIABILITIES AND SHAREHOLDERS' EQUITY
September 30, 2001 and December 31, 2000
(Unaudited)
2001 2000
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt $85,000 $100
Notes payable 667 667
Accounts payable:
Associated companies 108,768 94,776
Other 106,059 231,313
Customer deposits 31,856 29,775
Taxes accrued 192,020 40,263
Accumulated deferred income taxes - 55,127
Interest accrued 16,396 27,624
Obligations under capital leases 46,158 45,962
Other 71,938 14,942
---------- ----------
TOTAL 658,862 540,549
---------- ----------
DEFERRED CREDITS AND OTHER LIABILITIES
Accumulated deferred income taxes 742,847 715,891
Accumulated deferred investment tax credits 84,495 88,264
Obligations under capital leases 70,734 101,350
Transition to competition 142,923 119,553
Accumulated provisions 37,857 42,393
Other 101,204 64,267
---------- ----------
TOTAL 1,180,060 1,131,718
---------- ----------
Long-term debt 1,259,967 1,239,712
Company-obligated mandatorily redeemable
preferred securities of subsidiary trust holding
solely junior subordinated deferrable debentures 60,000 60,000
SHAREHOLDERS' EQUITY
Preferred stock without sinking fund 116,350 116,350
Common stock, $0.01 par value, authorized 325,000,000
shares; issued and outstanding 46,980,196 shares in 2001
and 2000 470 470
Paid-in capital 591,127 591,127
Retained earnings 641,803 548,285
---------- ----------
TOTAL 1,349,750 1,256,232
---------- ----------
Commitments and Contingencies (Notes 1 and 2)
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $4,508,639 $4,228,211
========== ==========
See Notes to Financial Statements.
ENTERGY ARKANSAS, INC.
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2001 and 2000
(Unaudited)
Three Months Ended Increase/
Description 2001 2000 (Decrease) %
(In Millions)
Electric Operating Revenues:
Residential $ 207.4 $ 209.6 ($2.2) (1)
Commercial 103.8 99.1 4.7 5
Industrial 109.2 106.4 2.8 3
Governmental 4.7 4.4 0.3 7
-------- -------- -------
Total retail 425.1 419.5 5.6 1
Sales for resale
Associated companies 63.3 59.1 4.2 7
Non-associated companies 57.1 65.7 (8.6) (13)
Other (3.9) 3.9 (7.8) (200)
-------- -------- -------
Total $ 541.6 $ 548.2 ($6.6) (1)
======== ======== =======
Billed Electric Energy
Sales (GWH):
Residential 2,332 2,424 (92) (4)
Commercial 1,608 1,615 (7) -
Industrial 1,923 2,020 (97) (5)
Governmental 71 70 1 1
-------- -------- -------
Total retail 5,934 6,129 (195) (3)
Sales for resale
Associated companies 1,673 1,216 457 38
Non-associated companies 1,320 1,341 (21) (2)
-------- -------- -------
Total 8,927 8,686 241 3
======== ======== =======
Nine Months Ended Increase/
Description 2001 2000 (Decrease) %
(In Millions)
Electric Operating Revenues:
Residential $ 471.7 $ 439.7 $ 32.0 7
Commercial 253.2 233.5 19.7 8
Industrial 279.2 264.0 15.2 6
Governmental 12.4 11.4 1.0 9
-------- -------- -------
Total retail 1,016.5 948.6 67.9 7
Sales for resale
Associated companies 183.1 197.6 (14.5) (7)
Non-associated companies 164.7 156.6 8.1 5
Other 24.2 40.1 (15.9) (40)
-------- -------- -------
Total $ 1,388.5 $ 1,342.9 $ 45.6 3
======== ======== =======
Billed Electric Energy
Sales (GWH):
Residential 5,568 5,276 292 6
Commercial 3,971 3,851 120 3
Industrial 5,270 5,386 (116) (2)
Governmental 188 182 6 3
-------- -------- -------
Total retail 14,997 14,695 302 2
Sales for resale
Associated companies 4,753 5,481 (728) (13)
Non-associated companies 3,947 3,832 115 3
-------- -------- -------
Total 23,697 24,008 (311) (1)
======== ======== =======
ENTERGY GULF STATES, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Net Income
Net income decreased for the three months ended September 30, 2001
compared to the three months ended September 30, 2000 primarily due to
decreased net revenue and increased interest expense, partially offset by
decreased other operation and maintenance expenses.
Net income decreased slightly for the nine months ended September 30,
2001 compared to the nine months ended September 30, 2000 as a result of
decreased net revenue and increased interest expense, largely offset by
increased interest income and decreased other operation and maintenance
expenses.
Revenues and Sales
Electric operating revenues
The changes in electric operating revenues for the three and nine
months ended September 30, 2001 are as follows:
Three Months Ended Nine Months Ended
Description Increase/(Decrease) Increase/(Decrease)
(In Millions)
Base rate changes ($2.1) ($3.0)
Fuel cost recovery (3.6) 317.0
Sales volume/weather (17.1) (5.5)
Other revenue (including unbilled) (60.6) (73.1)
Sales for resale (18.9) 31.8
------- ------
Total ($102.3) $267.2
======= ======
Fuel cost recovery
Entergy Gulf States is allowed to recover certain fuel and purchased
power costs through fuel mechanisms included in electric rates that are
recorded as fuel cost recovery revenues. The difference between revenues
collected and current fuel and purchased power costs is reflected as
deferred fuel costs on Entergy Gulf States' financial statements such that
these costs generally have no net effect on earnings.
Fuel cost recovery revenues decreased $39.8 million for the three
months ended September 30, 2001 in the Louisiana jurisdiction of Entergy
Gulf States due to lower fuel and purchased power costs. Fuel cost
recovery revenues increased $36.2 million for the three months ended
September 30, 2001 in the Texas jurisdiction of Entergy Gulf States due to
a higher fixed fuel factor and due to a fuel recovery surcharge which
became effective in February 2001.
Fuel cost recovery revenues increased for the nine months ended
September 30, 2001 in both operational jurisdictions of Entergy Gulf
States. In the Louisiana jurisdiction, fuel recovery revenues increased
$204 million for the nine months ended September 30, 2001 due to the
recovery through the fuel adjustment clause of higher fuel and purchased
power costs from early 2001. In the Louisiana jurisdiction, these fuel
costs are recovered on a two-month lag. In the Texas jurisdiction, fuel
cost recovery revenues increased $113 million for the nine months ended
September 30, 2001 due to increases in the fixed fuel factor in August
2000 and March 2001 and due to a fuel recovery surcharge which became
effective in February 2001.
ENTERGY GULF STATES, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Sales volume/weather
Electric sales vary seasonally in response to weather and usually
peak in the summer. Lower electric sales volume reduced revenues for the
three months ended September 30, 2001 primarily due to less favorable
weather. The effect of milder-than-normal summer weather in the third
quarter of 2001 decreased electric sales volume by 338 GWH in the
residential and commercial sectors. Lower usage in the industrial sector
of 533 GWH and 612 GWH for the three and nine months ended, respectively,
contributed to the decrease in electric sales.
Other revenue (including unbilled)
Unbilled revenue decreased $61 million for the three months ended
September 30, 2001 due to the effect of fuel prices in the Louisiana
jurisdiction in the period included in the September 2001 unbilled revenue
calculation compared to the calculation in the prior period.
Unbilled revenue decreased $69 million for the nine months ended
September 30, 2001 due to the effect of fuel prices for the Louisiana
jurisdiction and decreased volume for retail customers in the Louisiana
and Texas jurisdictions and wholesale customers in the Texas jurisdiction.
Sales for resale
Sales for resale decreased for the three months ended September 30,
2001 primarily due to decreased sales volume to affiliated customers and
to adjoining utility systems and due to decreased prices for resale
electricity.
Sales for resale increased for the nine months ended September 30,
2001 primarily due to increased sales volume to municipal and co-op
customers and due to increased prices for resale electricity.
Included in the sales for resale is the sale to adjoining utility
systems of power from the 30% share of River Bend acquired from Cajun,
which is not subject to state rate regulation.
Gas operating revenues
Gas operating revenues increased for the nine months ended September
30, 2001 due to a 76% average increase in the market price of natural gas,
particularly during the first and second quarters of 2001, and due to
increased sales volume, primarily during the first quarter of 2001. The
increase in gas revenues was largely offset by increased expense for gas
purchased for resale.
Expenses
Fuel and purchased power
Fuel and purchased power expenses increased for the nine months ended
September 30, 2001 due to:
o higher market prices for purchased power; and
o higher market prices for natural gas, which increased 23% over the
same period of 2000.
ENTERGY GULF STATES, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Other operation and maintenance
Other operation and maintenance expenses decreased for the three
months ended September 30, 2001 primarily due to:
o the disposal of low-level radioactive waste in 2000 of $4.0 million;
o a decrease in legal expenses of $1.9 million related to the
unbundling of services for transition to competition;
o a decrease in maintenance of overhead lines of $1.6 million; and
o a decrease in expenses for injuries and damages of $1.1 million.
Other regulatory credits
Other regulatory credits increased for the three and nine months
ended September 30, 2001 primarily due to the amount of capacity charges
included in purchased power costs for the summers of 2000 and 2001 that
Entergy Gulf States deferred and expects to recover in the future.
Other
Other income
Other income increased $9.6 million for the nine months ended
September 30, 2001 primarily due to increased interest income recorded on
the deferred fuel balance.
Interest and other charges
Interest expense increased for the three months ended September 30,
2001 primarily due to an adjustment to the liability for deferred
compensation for certain former Entergy Gulf States employees in accord
with an actuarial study.
Interest expense increased for the nine months ended September 30,
2001 primarily due to:
o the issuance of $300 million of long-term debt in June 2000 and the
net issuance of an additional $177 million of long-term debt in August
2001;
o increased interest expense on refund provisions; and
o an adjustment to the liability for deferred compensation for certain
former Entergy Gulf States employees in accord with an actuarial study.
Income taxes
The effective income tax rates for the three months ended September
30, 2001 and 2000 were 36.2% and 38.2%, respectively. The effective
income tax rates for the nine months ended September 30, 2001 and 2000
were 36.1% and 37.0%, respectively.
ENTERGY GULF STATES, INC.
INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2001 and 2000
(Unaudited)
Three Months Ended Nine Months Ended
2001 2000 2001 2000
(In Thousands) (In Thousands)
OPERATING REVENUES
Domestic electric $708,951 $811,265 $2,129,424 $1,862,171
Natural gas 5,537 5,887 50,434 24,584
-------- -------- ---------- ----------
TOTAL 714,488 817,152 2,179,858 1,886,755
-------- -------- ---------- ----------
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale 281,276 279,411 881,440 639,950
Purchased power 136,703 141,226 404,558 328,506
Nuclear refueling outage expenses 2,680 4,990 8,792 13,573
Other operation and maintenance 107,991 116,480 309,404 313,720
Decommissioning 1,562 1,568 4,685 4,705
Taxes other than income taxes 32,028 35,295 90,587 90,053
Depreciation and amortization 48,683 47,599 143,634 140,977
Other regulatory credits - net (16,038) (955) (23,393) (12,746)
Amortization of rate deferrals 1,402 1,402 4,205 4,205
-------- -------- ---------- ----------
TOTAL 596,287 627,016 1,823,912 1,522,943
-------- -------- ---------- ----------
OPERATING INCOME 118,201 190,136 355,946 363,812
-------- -------- ---------- ----------
OTHER INCOME
Allowance for equity funds used during construction 2,650 2,189 6,817 5,675
Gain on sale of assets 623 549 1,811 1,595
Miscellaneous - net 4,957 4,910 16,609 8,320
-------- -------- ---------- ----------
TOTAL 8,230 7,648 25,237 15,590
-------- -------- ---------- ----------
INTEREST AND OTHER CHARGES
Interest on long-term debt 37,359 39,036 115,511 106,225
Other interest - net 7,844 1,415 12,038 4,524
Distributions on preferred securities of subsidiary 1,859 1,859 5,578 5,578
Allowance for borrowed funds used during construction (2,704) (1,973) (6,858) (5,185)
-------- -------- ---------- ----------
TOTAL 44,358 40,337 126,269 111,142
-------- -------- ---------- ----------
INCOME BEFORE INCOME TAXES 82,073 157,447 254,914 268,260
Income taxes 29,720 60,122 92,133 99,363
-------- -------- ---------- ----------
NET INCOME 52,353 97,325 162,781 168,897
Preferred dividend requirements and other 1,201 1,349 3,782 8,668
-------- -------- ---------- ----------
EARNINGS APPLICABLE TO
COMMON STOCK $51,152 $95,976 $158,999 $160,229
======== ======== ========== ==========
See Notes to Financial Statements.
ENTERGY GULF STATES, INC.
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2001 and 2000
(Unaudited)
2001 2000
(In Thousands)
OPERATING ACTIVITIES
Net income $162,781 $168,897
Noncash items included in net income:
Amortization of rate deferrals 4,205 4,205
Reserve for regulatory adjustments (22,880) (82,637)
Other regulatory credits - net (23,393) (12,746)
Depreciation, amortization, and decommissioning 148,319 145,682
Deferred income taxes and investment tax credits (17,478) 19,866
Allowance for equity funds used during construction (6,817) (5,675)
Gain on sale of assets (1,811) (1,595)
Changes in working capital:
Receivables (69,940) (129,735)
Fuel inventory (17,057) (2,515)
Accounts payable (163,428) 4,179
Taxes accrued 120,593 95,878
Interest accrued 5,776 20,172
Deferred fuel costs 118,427 (1,240)
Other working capital accounts 15,914 12,769
Provision for estimated losses and reserves (4,539) (3,195)
Changes in other regulatory assets (31,610) (27,392)
Other 31,876 37,427
-------- --------
Net cash flow provided by operating activities 248,938 242,345
-------- --------
INVESTING ACTIVITIES
Construction expenditures (224,101) (195,304)
Allowance for equity funds used during construction 6,817 5,675
Nuclear fuel purchases (3,937) (34,707)
Proceeds from sale/leaseback of nuclear fuel 3,937 34,150
Decommissioning trust contributions and realized
change in trust assets (9,245) (8,364)
Changes in other temporary investments - net (75,777) -
Other regulatory investments (22,628) (80,516)
-------- --------
Net cash flow used in investing activities (324,934) (279,066)
-------- --------
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt 300,000 298,855
Retirement of:
Long-term debt (122,750) -
Redemption of preferred stock (4,574) (156,260)
Dividends paid:
Common stock (78,500) (73,400)
Preferred stock (3,830) (9,540)
-------- --------
Net cash flow provided by financing activities 90,346 59,655
-------- --------
Net increase in cash and cash equivalents 14,350 22,934
Cash and cash equivalents at beginning of period 68,279 32,312
-------- --------
Cash and cash equivalents at end of period $82,629 $55,246
======== ========
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized $117,903 $91,865
Income taxes $920 $7,659
Noncash investing and financing activities:
Change in unrealized appreciation/(depreciation) of
decommissioning trust assets ($10,172) $15,500
See Notes to Financial Statements.
ENTERGY GULF STATES, INC.
BALANCE SHEETS
ASSETS
September 30, 2001 and December 31, 2000
(Unaudited)
2001 2000
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash $23,419 $10,726
Temporary cash investments - at cost,
which approximates market 59,210 57,553
---------- ----------
Total cash and cash equivalents 82,629 68,279
---------- ----------
Other temporary investments 75,777 -
Accounts receivable:
Customer 143,924 125,412
Allowance for doubtful accounts (2,131) (2,131)
Associated companies 83,714 27,660
Other 34,610 22,837
Accrued unbilled revenues 119,985 136,384
---------- ----------
Total accounts receivable 380,102 310,162
---------- ----------
Deferred fuel costs 192,327 288,126
Fuel inventory - at average cost 54,315 37,258
Materials and supplies - at average cost 96,687 100,018
Rate deferrals 1,402 5,606
Prepayments and other 24,562 22,332
---------- ----------
TOTAL 907,801 831,781
---------- ----------
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds 242,628 243,555
Non-utility property - at cost (less accumulated depreciation) 194,425 194,422
Other - at cost (less accumulated depreciation) 16,100 14,826
---------- ----------
TOTAL 453,153 452,803
---------- ----------
UTILITY PLANT
Electric 7,612,205 7,574,905
Property under capital lease 30,355 38,564
Natural gas 58,865 56,163
Construction work in progress 261,008 144,814
Nuclear fuel under capital lease 48,990 57,472
---------- ----------
TOTAL UTILITY PLANT 8,011,423 7,871,918
Less - accumulated depreciation and amortization 3,753,230 3,680,662
---------- ----------
UTILITY PLANT - NET 4,258,193 4,191,256
---------- ----------
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
SFAS 109 regulatory asset - net 413,360 403,934
Unamortized loss on reacquired debt 35,216 37,903
Other regulatory assets 191,589 169,405
Long-term receivables 27,360 29,586
Other 23,504 17,349
---------- ----------
TOTAL 691,029 658,177
---------- ----------
TOTAL ASSETS $6,310,176 $6,134,017
========== ==========
See Notes to Financial Statements.
ENTERGY GULF STATES, INC.
BALANCE SHEETS
LIABILITIES AND SHAREHOLDERS' EQUITY
September 30, 2001 and December 31, 2000
(Unaudited)
2001 2000
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt $150,000 $122,750
Accounts payable:
Associated companies 40,691 66,312
Other 120,722 258,529
Customer deposits 43,468 37,489
Taxes accrued 252,961 132,368
Accumulated deferred income taxes 47,905 94,032
Nuclear refueling outage costs 16,163 10,209
Interest accrued 49,315 43,539
Obligations under capital leases 41,130 42,524
Other 24,109 19,418
---------- ----------
TOTAL 786,464 827,170
---------- ----------
DEFERRED CREDITS AND OTHER LIABILITIES
Accumulated deferred income taxes 1,162,627 1,115,119
Accumulated deferred investment tax credits 165,575 171,000
Obligations under capital leases 38,214 53,512
Other regulatory liabilities - 669
Decommissioning 145,076 142,604
Transition to competition 79,098 72,381
Regulatory reserves 38,085 60,965
Accumulated provisions 62,865 67,404
Other 81,380 98,501
---------- ----------
TOTAL 1,772,920 1,782,155
---------- ----------
Long-term debt 1,959,054 1,808,879
Preferred stock with sinking fund 26,185 30,758
Company-obligated mandatorily redeemable
preferred securities of subsidiary trust holding
solely junior subordinated deferrable debentures 85,000 85,000
SHAREHOLDERS' EQUITY
Preferred stock without sinking fund 47,677 47,677
Common stock, no par value, authorized 200,000,000
shares; issued and outstanding 100 shares in 2001 and 2000 114,055 114,055
Paid-in capital 1,153,253 1,153,195
Retained earnings 365,568 285,128
---------- ----------
TOTAL 1,680,553 1,600,055
---------- ----------
Commitments and Contingencies (Notes 1 and 2)
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $6,310,176 $6,134,017
========== ==========
See Notes to Financial Statements.
ENTERGY GULF STATES, INC.
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2001 and 2000
(Unaudited)
Three Months Ended Increase/
Description 2001 2000 (Decrease) %
(In Millions)
Electric Operating Revenues:
Residential $ 256.8 $ 237.8 $ 19.0 8
Commercial 159.9 133.2 26.7 20
Industrial 208.6 221.8 (13.2) (6)
Governmental 9.6 7.7 1.9 25
------- ------- ------
Total retail 634.9 600.5 34.4 6
Sales for resale
Associated companies 40.0 63.5 (23.5) (37)
Non-associated companies 36.2 31.6 4.6 15
Other (2.1) 115.7 (117.8) (102)
------- ------- -------
Total $ 709.0 $ 811.3 ($102.3) (13)
======= ======= =======
Billed Electric Energy
Sales (GWH):
Residential 3,045 3,340 (295) (9)
Commercial 2,238 2,290 (52) (2)
Industrial 3,948 4,481 (533) (12)
Governmental 121 122 (1) (1)
------- ------- -------
Total retail 9,352 10,233 (881) (9)
Sales for resale
Associated companies 557 769 (212) (28)
Non-associated companies 801 698 103 15
------- ------- -------
Total 10,710 11,700 (990) (8)
======= ======= =======
Nine Months Ended Increase/
Description 2001 2000 (Decrease) %
(In Millions)
Electric Operating Revenues:
Residential $ 639.6 $ 534.7 $ 104.9 20
Commercial 461.9 362.3 99.6 27
Industrial 774.4 614.5 159.9 26
Governmental 29.9 23.5 6.4 27
------- ------- -------
Total retail 1,905.8 1,535.0 370.8 24
Sales for resale
Associated companies 69.3 81.9 (12.6) (15)
Non-associated companies 120.8 76.4 44.4 58
Other 33.5 168.9 (135.4) (80)
------- ------- -------
Total $ 2,129.4 $ 1,862.2 $ 267.2 14
========= ========= =======
Billed Electric Energy
Sales (GWH):
Residential 7,188 7,274 (86) (1)
Commercial 5,819 5,795 24 -
Industrial 12,784 13,396 (612) (5)
Governmental 342 336 6 2
------- ------- -------
Total retail 26,133 26,801 (668) (2)
Sales for resale
Associated companies 1,005 1,205 (200) (17)
Non-associated companies 2,496 2,266 230 10
------- ------- -------
Total 29,634 30,272 (638) (2)
======= ======= =======
ENTERGY LOUISIANA, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Net Income
Net income increased for the three months ended September 30, 2001
compared to the three months ended September 30, 2000 primarily due to
receipt of a final FERC order that will result in a refund from System
Energy. The accounting entries necessary to record the effects of the
order reduced purchased power expenses. See Note 2 to the financial
statements for further discussion of System Energy's rate proceeding.
Increased regulatory credits also increased net income, and the increase
was partially offset by decreased net revenue.
Net income decreased for the nine months ended September 30, 2001
compared to the nine months ended September 30, 2000 primarily due to
decreased net revenue and increased interest expense, partially offset by
the effect of the final FERC order in the System Energy rate proceeding,
increased regulatory credits, and decreased other operation and
maintenance expenses.
Revenues and Sales
The changes in electric operating revenues for the three and nine
months ended September 30, 2001 are as follows:
Three Months Ended Nine Months Ended
Description Increase/(Decrease) Increase/(Decrease)
(In Millions)
Base rate changes $0.3 ($7.6)
Fuel cost recovery (169.1) 166.2
Sales volume/weather (27.0) (27.1)
Other revenue (including unbilled) (45.7) (72.6)
Sales for resale (7.3) (5.9)
------- -----
Total ($248.8) $53.0
======= =====
Base rate changes
Base rate changes decreased for the nine months ended September 30,
2001 primarily due to additional formula rate plan reductions effective
August 2000, partially offset by higher prices for special-use industrial
customers as a result of decreased usage which is reflected in sales
volume/weather.
Fuel cost recovery
Entergy Louisiana is allowed to recover certain fuel and purchased
power costs through fuel mechanisms included in electric rates that are
recorded as fuel cost recovery revenues. The difference between revenues
collected and current fuel and purchased power costs is reflected as
deferred fuel costs on Entergy Louisiana's financial statements such that
these costs generally have no net effect on earnings.
Fuel cost recovery revenues decreased for the three months ended
September 30, 2001 primarily due to decreased fuel and purchased power
expenses as a result of decreased market prices of natural gas and
purchased power in addition to fuel-related refunds that occurred in July
through September 2001. See Note 2 to the financial statements herein for
a discussion of the fuel-related refunds.
ENTERGY LOUISIANA, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Fuel cost recovery revenues increased for the nine months ended
September 30, 2001 due to the recovery through the fuel adjustment clause
of higher fuel and purchased power expenses. The increase in fuel and
purchased power expenses was primarily due to the increased market prices
of natural gas and purchased power early in 2001.
Sales volume/weather
Lower electric sales volume reduced revenues for the three and nine
months ended September 30, 2001 because of decreased usage of 114 GWH and
599 GWH, respectively, in the industrial sector. The decreased usage in
the industrial sector resulted in higher rates for that sector, which is
reflected in base rate changes. Electric sales vary seasonally in
response to weather and usually peak in the summer. The effect of milder-
than-normal summer weather also decreased usage by 404 GWH and 230 GWH for
the three and nine months ended, respectively, in the residential and
commercial sectors.
Other revenue (including unbilled)
Unbilled revenue decreased $51.2 million and $78.6 million for the
three and nine months ended September 30, 2001, respectively, primarily
due to the effect of lower fuel prices for the period included in the
September 2001 unbilled revenue calculation compared to the calculation in
the prior year.
Sales for resale
Sales for resale decreased for the three and nine months ended
September 30, 2001 primarily due to a decrease in sales volume as a result
of decreased generation, coupled with a decrease in the average market
price of energy.
Expenses
Fuel and purchased power
Fuel and purchased power expenses decreased for the three months
ended September 30, 2001 primarily due to:
o decreased market prices of natural gas and purchased power;
o decreased generation requirements; and
o the reduction of $67.5 million in purchased power expenses as a
result of the FERC-ordered refund from System Entergy.
Fuel and purchased power expenses increased for the nine months
ended September 30, 2001 primarily due to higher market prices of natural
gas and purchased power early in 2001, partially offset by the FERC-
ordered refund from System Energy and decreased generation requirements.
Other operation and maintenance
Other operation and maintenance expenses decreased for the nine
months ended September 30, 2001 primarily due to a decrease of $7.0
million in plant maintenance expenses as a result of prior year
maintenance outages at Waterford 3 and certain fossil plants.
ENTERGY LOUISIANA, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Other regulatory charges (credits)
Other regulatory credits increased for the three and nine months
ended September 30, 2001 primarily due to the amount of capacity charges
included in purchased power costs for the summers of 2000 and 2001 that
Entergy Louisiana deferred and expects to recover in the future.
Other
Other income
Other income decreased for the three months ended September 30, 2001
primarily due to a decrease in interest recorded on deferred fuel
balances.
Interest and other charges
Other interest increased for the three and nine months ended
September 30, 2001 primarily due to interest accrued on reserves provided
for fuel-related refunds that were refunded in July through September
2001.
Income taxes
The effective income tax rates for the three months ended September
30, 2001 and 2000 were 39.3% and 39.5%, respectively. The effective
income tax rates for the nine months ended September 30, 2001 and 2000
were 40.1% and 40.2%, respectively.
ENTERGY LOUISIANA, INC.
INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2001 and 2000
(Unaudited)
Three Months Ended Nine Months Ended
2001 2000 2001 2000
(In Thousands) (In Thousands)
OPERATING REVENUES
Domestic electric $473,342 $722,175 $1,570,040 $1,517,063
-------- -------- ---------- ----------
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale 93,989 235,362 518,458 367,301
Purchased power 69,841 160,360 337,831 394,479
Nuclear refueling outage expenses 3,050 3,410 9,574 10,230
Other operation and maintenance 76,131 77,435 217,214 225,608
Decommissioning 2,606 2,606 7,818 7,817
Taxes other than income taxes 20,314 21,173 57,031 55,889
Depreciation and amortization 44,016 42,700 129,460 127,029
Other regulatory charges (credits) - net (29,133) 240 (28,053) 720
-------- -------- ---------- ----------
TOTAL 280,814 543,286 1,249,333 1,189,073
-------- -------- ---------- ----------
OPERATING INCOME 192,528 178,889 320,707 327,990
-------- -------- ---------- ----------
OTHER INCOME
Allowance for equity funds used during construction 1,301 1,373 3,462 3,252
Gain on sale of assets - - 152 -
Miscellaneous - net 664 2,641 3,344 3,184
-------- -------- ---------- ----------
TOTAL 1,965 4,014 6,958 6,436
-------- -------- ---------- ----------
INTEREST AND OTHER CHARGES
Interest on long-term debt 24,176 25,418 73,366 73,360
Other interest - net 2,368 1,212 9,455 5,158
Distributions on preferred securities of subsidiary 1,575 1,575 4,725 4,725
Allowance for borrowed funds used during construction (987) (1,046) (2,619) (2,914)
-------- -------- ---------- ----------
TOTAL 27,132 27,159 84,927 80,329
-------- -------- ---------- ----------
INCOME BEFORE INCOME TAXES 167,361 155,744 242,738 254,097
Income taxes 65,846 61,577 97,329 102,051
-------- -------- ---------- ----------
NET INCOME 101,515 94,167 145,409 152,046
Preferred dividend requirements and other 1,061 2,378 5,818 7,135
-------- -------- ---------- ----------
EARNINGS APPLICABLE TO
COMMON STOCK $100,454 $91,789 $139,591 $144,911
======== ======== ========== ==========
See Notes to Financial Statements.
ENTERGY LOUISIANA, INC.
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2001 and 2000
(Unaudited)
2001 2000
(In Thousands)
OPERATING ACTIVITIES
Net income $145,409 $152,046
Noncash items included in net income:
Reserve for regulatory adjustments (11,456) -
Other regulatory charges (credits) - net (28,053) 720
Depreciation, amortization, and decommissioning 137,278 134,846
Deferred income taxes and investment tax credits (55,380) (1,395)
Allowance for equity funds used during construction (3,462) (3,252)
Gain on sale of assets (152) -
Changes in working capital:
Receivables (21,389) (141,381)
Accounts payable (97,696) (65,280)
Taxes accrued 180,533 130,070
Interest accrued (8,139) 9,015
Deferred fuel costs 127,247 (69,348)
Other working capital accounts (68,284) 45,542
Provision for estimated losses and reserves 1,499 3,378
Changes in other regulatory assets (31,841) 16,732
Other 46,173 2,834
-------- --------
Net cash flow provided by operating activities 312,287 214,527
-------- --------
INVESTING ACTIVITIES
Construction expenditures (146,418) (135,442)
Allowance for equity funds used during construction 3,462 3,252
Nuclear fuel purchases - (29,317)
Proceeds from sale/leaseback of nuclear fuel - 29,317
Decommissioning trust contributions and realized
change in trust assets (12,638) (8,700)
Changes in other temporary investments - net (9,214) -
-------- --------
Net cash flow used in investing activities (164,808) (140,890)
-------- --------
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt - 148,754
Retirement of:
Long-term debt (35,088) (100,000)
Redemption of preferred stock (35,000) -
Dividends paid:
Common stock (85,500) (57,800)
Preferred stock (7,369) (7,135)
-------- --------
Net cash flow used in financing activities (162,957) (16,181)
-------- --------
Net increase (decrease) in cash and cash equivalents (15,478) 57,456
Cash and cash equivalents at beginning of period 43,959 7,734
-------- --------
Cash and cash equivalents at end of period $28,481 $65,190
======== ========
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized $91,077 $68,913
Income taxes $550 $9,156
Noncash investing and financing activities:
Change in unrealized appreciation/(depreciation) of
decommissioning trust assets ($4,792) $4,396
See Notes to Financial Statements.
ENTERGY LOUISIANA, INC.
BALANCE SHEETS
ASSETS
September 30, 2001 and December 31, 2000
(Unaudited)
2001 2000
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash $21,844 $14,138
Temporary cash investments - at cost,
which approximates market 6,637 29,821
---------- ----------
Total cash and cash equivalents 28,481 43,959
---------- ----------
Other temporary investments 9,214 -
Notes receivable 8 1,510
Accounts receivable:
Customer 101,075 111,292
Allowance for doubtful accounts (1,771) (1,771)
Associated companies 93,853 30,518
Other 10,717 13,698
Accrued unbilled revenues 123,952 152,700
---------- ----------
Total accounts receivable 327,826 306,437
---------- ----------
Deferred fuel costs - 84,051
Accumulated deferred income taxes 28,030 -
Materials and supplies - at average cost 76,730 77,389
Deferred nuclear refueling outage costs 7,115 16,425
Prepayments and other 11,098 9,996
---------- ----------
TOTAL 488,502 539,767
---------- ----------
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity 14,230 14,230
Decommissioning trust funds 118,109 110,263
Non-utility property - at cost (less accumulated depreciation) 21,716 21,700
---------- ----------
TOTAL 154,055 146,193
---------- ----------
UTILITY PLANT
Electric 5,416,378 5,357,920
Property under capital lease 238,427 238,427
Construction work in progress 133,640 85,299
Nuclear fuel under capital lease 39,019 63,923
---------- ----------
TOTAL UTILITY PLANT 5,827,464 5,745,569
Less - accumulated depreciation and amortization 2,533,080 2,441,937
---------- ----------
UTILITY PLANT - NET 3,294,384 3,303,632
---------- ----------
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
SFAS 109 regulatory asset - net 209,176 204,810
Unamortized loss on reacquired debt 29,566 33,244
Other regulatory assets 78,356 50,881
Long-term receivables 1,510 -
Other 16,713 10,882
---------- ----------
TOTAL 335,321 299,817
---------- ----------
TOTAL ASSETS $4,272,262 $4,289,409
========== ==========
See Notes to Financial Statements.
ENTERGY LOUISIANA, INC.
BALANCE SHEETS
LIABILITIES AND SHAREHOLDERS' EQUITY
September 30, 2001 and December 31, 2000
(Unaudited)
2001 2000
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt $170,368 $35,088
Accounts payable:
Associated companies 33,272 71,948
Other 85,821 144,841
Customer deposits 61,108 60,227
Taxes accrued 203,840 23,307
Accumulated deferred income taxes - 20,545
Interest accrued 27,397 35,536
Deferred fuel cost 43,196 -
Obligations under capital leases 34,274 34,274
Other 23,105 102,614
---------- ----------
TOTAL 682,381 528,380
---------- ----------
DEFERRED CREDITS AND OTHER LIABILITIES
Accumulated deferred income taxes 762,049 757,362
Accumulated deferred investment tax credits 113,305 117,393
Obligations under capital leases 4,745 29,649
Regulatory reserves - 11,456
Accumulated provisions 65,700 64,201
Other 75,920 61,724
---------- ----------
TOTAL 1,021,719 1,041,785
---------- ----------
Long-term debt 1,106,523 1,276,696
Preferred stock with sinking fund - 35,000
Company-obligated mandatorily redeemable
preferred securities of subsidiary trust holding
solely junior subordinated deferrable debentures 70,000 70,000
SHAREHOLDERS' EQUITY
Preferred stock without sinking fund 100,500 100,500
Common stock, no par value, authorized 250,000,000
shares; issued and outstanding 165,173,180 shares in 2001
and 2000 1,088,900 1,088,900
Capital stock expense and other (2,171) (2,171)
Retained earnings 204,410 150,319
---------- ----------
TOTAL 1,391,639 1,337,548
---------- ----------
Commitments and Contingencies (Notes 1 and 2)
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $4,272,262 $4,289,409
========== ==========
See Notes to Financial Statements.
ENTERGY LOUISIANA, INC.
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2001 and 2000
(Unaudited)
Three Months Ended Increase/
Description 2001 2000 (Decrease) %
(In Millions)
Electric Operating Revenues:
Residential $ 192.8 $ 284.1 ($91.3) (32)
Commercial 106.0 145.9 (39.9) (27)
Industrial 149.7 219.7 (70.0) (32)
Governmental 8.7 11.6 (2.9) (25)
------- ------- ------
Total retail 457.2 661.3 (204.1) (31)
Sales for resale
Associated companies 9.2 15.0 (5.8) (39)
Non-associated companies 7.8 9.3 (1.5) (16)
Other (0.8) 36.6 (37.4) (102)
------- ------- ------
Total $ 473.4 $ 722.2 ($248.8) (34)
======= ======= =======
Billed Electric Energy
Sales (GWH):
Residential 2,749 3,103 (354) (11)
Commercial 1,572 1,650 (78) (5)
Industrial 3,675 3,789 (114) (3)
Governmental 132 131 1 1
------- ------- ------
Total retail 8,128 8,673 (545) (6)
Sales for resale
Associated companies 108 152 (44) (29)
Non-associated companies 114 122 (8) (7)
------- ------- ------
Total 8,350 8,947 (597) (7)
======= ======= ======
Nine Months Ended Increase/
Description 2001 2000 (Decrease) %
(In Millions)
Electric Operating Revenues:
Residential $ 541.1 $ 546.4 ($5.3) (1)
Commercial 342.0 324.1 17.9 6
Industrial 613.1 533.2 79.9 15
Governmental 31.5 27.9 3.6 13
--------- --------- ------
Total retail 1,527.7 1,431.6 96.1 7
Sales for resale
Associated companies 20.6 15.7 4.9 31
Non-associated companies 20.0 30.8 (10.8) (35)
Other 1.7 38.9 (37.2) (96)
--------- --------- ------
Total $ 1,570.0 $ 1,517.0 $ 53.0 3
========= ========= ======
Billed Electric Energy
Sales (GWH):
Residential 6,532 6,775 (243) (4)
Commercial 4,080 4,094 (14) -
Industrial 10,832 11,431 (599) (5)
Governmental 380 362 18 5
--------- --------- ------
Total retail 21,824 22,662 (838) (4)
Sales for resale
Associated companies 269 168 101 60
Non-associated companies 289 435 (146) (34)
--------- --------- ------
Total 22,382 23,265 (883) (4)
========= ========= ======
ENTERGY MISSISSIPPI, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Net Income
Net income increased for the nine months ended September 30, 2001
compared to the nine months ended September 30, 2000 primarily due to
decreased other operation and maintenance expenses and increased interest
income, partially offset by decreased unbilled revenues and increased
interest expense.
Revenues and Sales
The changes in electric operating revenues for the three and nine
months ended September 30, 2001 are as follows:
Three Months Ended Nine Months Ended
Description Increase/(Decrease) Increase/(Decrease)
(In Millions)
Base rate changes $4.2 $3.2
Grand Gulf rate rider (9.6) (12.5)
Fuel cost recovery 68.6 136.0
Sales volume/weather (8.1) (1.0)
Other revenue (including unbilled) 1.8 (2.5)
Sales for resale (0.3) 65.3
----- ------
Total $56.6 $188.5
===== ======
Base rate changes
Base rate changes increased for the three and nine months ended
September 30, 2001 primarily due to an annual rate increase of $5.6
million under the formula rate plan, which became effective May 2001.
Grand Gulf rate rider
Rate rider revenues have no material effect on net income because
specific incurred expenses offset them.
Grand Gulf rate rider revenue decreased for the three and nine
months ended September 30, 2001 as a result of a lower rider which became
effective October 2000.
Fuel cost recovery
Entergy Mississippi is allowed to recover certain fuel and purchased
power costs through fuel mechanisms included in electric rates, recorded
as fuel cost recovery revenues. The difference between revenues collected
and current fuel and purchased power costs is reflected as deferred fuel
costs on Entergy Mississippi's financial statements such that these costs
generally have no net effect on earnings.
ENTERGY MISSISSIPPI, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Fuel cost recovery revenues increased for the three and nine months
ended September 30, 2001 primarily due to an increase in the energy cost
recovery rider to collect the under-recovered fuel and purchased power
costs incurred as of September 30, 2000. The recovery of $136.7 million,
plus carrying charges, will occur over a 24-month period, which began in
January 2001. The increase was also due to an additional increase in the
energy cost recovery rider effective April 2001.
Sales volume/weather
Electric sales vary seasonally in response to weather and usually
peak in the summer. Lower electric sales volume reduced revenues for the
three months ended September 30, 2001 due to decreased usage of 310 GWH in
the residential and commercial sectors as a result of milder-than-normal
summer weather. The decrease was also due to decreased usage of 61 GWH in
the industrial sector.
Sales for resale
Sales for resale increased for the nine months ended September 30,
2001 primarily due to increased net generation resulting in more energy
available for sale. The increase came from sales to affiliates, which are
generally made at a low margin. The increase was partially offset by a
decrease in the average market price of energy.
Expenses
Fuel and purchased power
Fuel and purchased power expenses increased for the three months
ended September 30, 2001 primarily due to an over-recovery of fuel costs.
The three months ended increase was partially offset by the decreased
market price of natural gas.
Fuel and purchased power increased for the nine months ended
September 30, 2001 primarily due to the increased market prices of natural
gas, oil, and purchased power.
Other operation and maintenance
Other operation and maintenance expenses decreased for the three and
nine months ended September 30, 2001 primarily due to a decrease of $2.6
million and $11.5 million, respectively, in plant maintenance expenses due
to outage costs at certain fossil plants in 2000. The nine months ended
decrease was partially offset by the following:
o increased charitable donations of $1.9 million; and
o return to service costs of $1.0 million for the Natchez steam plant.
Other regulatory charges (credits)
Other regulatory charges decreased for the three months ended
September 30, 2001 primarily due to a smaller over-recovery of Grand Gulf
costs.
Other regulatory credits increased for the nine months ended
September 30, 2001 primarily due to a greater under-recovery of Grand Gulf
costs in 2001.
ENTERGY MISSISSIPPI, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Other
Other income
Interest income increased for the three and nine months ended
September 30, 2001 primarily due to interest recorded on the deferred fuel
balance as a result of an MPSC order providing for a 24-month recovery of
the September 2000 under-recovered deferred fuel balance of $136.7
million.
Interest and other charges
Interest on long-term debt increased for the nine months ended
September 30, 2001 primarily due to the issuance of $120 million of long-
term debt in February 2000 and the issuance of $70 million of long-term
debt in January 2001.
Income taxes
The effective income tax rates for the three months ended September
30, 2001 and 2000 were 36.7% and 37.2%, respectively. The effective income
tax rates for the nine months ended September 30, 2001 and 2000 were 35.3%
and 35.6%, respectively.
ENTERGY MISSISSIPPI, INC.
INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2001 and 2000
(Unaudited)
Three Months Ended Nine Months Ended
2001 2000 2001 2000
(In Thousands) (In Thousands)
OPERATING REVENUES
Domestic electric $354,518 $297,966 $884,824 $696,346
-------- -------- -------- --------
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale 145,168 65,656 350,720 140,986
Purchased power 104,352 111,677 282,190 283,544
Other operation and maintenance 40,230 42,390 112,951 121,093
Taxes other than income taxes 12,962 12,906 36,027 34,174
Depreciation and amortization 12,751 12,292 36,966 35,994
Other regulatory charges (credits) - net 4,753 16,750 (14,502) 2,262
-------- -------- -------- --------
TOTAL 320,216 261,671 804,352 618,053
-------- -------- -------- --------
OPERATING INCOME 34,302 36,295 80,472 78,293
-------- -------- -------- --------
OTHER INCOME
Allowance for equity funds used during construction 784 662 1,799 1,912
Miscellaneous - net 6,625 2,246 14,772 6,656
-------- -------- -------- --------
TOTAL 7,409 2,908 16,571 8,568
-------- -------- -------- --------
INTEREST AND OTHER CHARGES
Interest on long-term debt 11,745 11,012 35,048 31,026
Other interest - net 1,039 673 3,351 2,370
Allowance for borrowed funds used during construction (685) (518) (1,548) (1,502)
-------- -------- -------- --------
TOTAL 12,099 11,167 36,851 31,894
-------- -------- -------- --------
INCOME BEFORE INCOME TAXES 29,612 28,036 60,192 54,967
Income taxes 10,864 10,425 21,236 19,556
-------- -------- -------- --------
NET INCOME 18,748 17,611 38,956 35,411
Preferred dividend requirements and other 555 842 2,240 2,527
-------- -------- -------- --------
EARNINGS APPLICABLE TO
COMMON STOCK $18,193 $16,769 $36,716 $32,884
======== ======== ======== ========
See Notes to Financial Statements.
ENTERGY MISSISSIPPI, INC.
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2001 and 2000
(Unaudited)
2001 2000
(In Thousands)
OPERATING ACTIVITIES
Net income $38,956 $35,411
Noncash items included in net income:
Other regulatory charges (credits) - net (14,502) 2,262
Depreciation and amortization 36,966 35,994
Deferred income taxes and investment tax credits (66,707) 23,697
Allowance for equity funds used during construction (1,799) (1,912)
(Gain)/loss on sale of assets (3) 2
Changes in working capital:
Receivables (201,114) (30,932)
Fuel inventory (2,042) 705
Accounts payable (14,127) (9,520)
Taxes accrued 81,226 18,406
Interest accrued 3,370 3,609
Deferred fuel costs 23,844 36,679
Other working capital accounts 16,765 4,021
Provision for estimated losses and reserves (4,100) (699)
Changes in other regulatory assets 135,154 (17,643)
Other 31,242 20,612
-------- --------
Net cash flow provided by operating activities 63,129 120,692
-------- --------
INVESTING ACTIVITIES
Construction expenditures (106,273) (91,895)
Allowance for equity funds used during construction 1,799 1,912
Other regulatory investments - (124,851)
-------- --------
Net cash flow used in investing activities (104,474) (214,834)
-------- --------
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt 69,620 119,057
Dividends paid:
Common stock (17,300) (18,000)
Preferred stock (2,527) (2,527)
-------- --------
Net cash flow provided by financing activities 49,793 98,530
-------- --------
Net increase in cash and cash equivalents 8,448 4,388
Cash and cash equivalents at beginning of period 5,113 4,787
-------- --------
Cash and cash equivalents at end of period $13,561 $9,175
======== ========
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid/(received) during the period for:
Interest - net of amount capitalized $33,114 $28,060
Income taxes - ($28,748)
See Notes to Financial Statements.
ENTERGY MISSISSIPPI, INC.
BALANCE SHEETS
ASSETS
September 30, 2001 and December 31, 2000
(Unaudited)
2001 2000
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents $13,561 $5,113
Accounts receivable:
Customer 86,174 44,517
Allowance for doubtful accounts (1,044) (1,044)
Associated companies 179,083 10,741
Other 2,579 9,964
Accrued unbilled revenues 32,100 33,600
---------- ----------
Total accounts receivable 298,892 97,778
---------- ----------
Deferred fuel costs 114,299 64,950
Fuel inventory - at average cost 5,478 3,436
Materials and supplies - at average cost 17,459 18,485
Prepayments and other 7,119 3,004
---------- ----------
TOTAL 456,808 192,766
---------- ----------
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity 5,531 5,531
Non-utility property - at cost (less accumulated depreciation) 6,755 6,851
---------- ----------
TOTAL 12,286 12,382
---------- ----------
UTILITY PLANT
Electric 1,914,826 1,885,501
Property under capital lease 219 290
Construction work in progress 101,566 44,085
---------- ----------
TOTAL UTILITY PLANT 2,016,611 1,929,876
Less - accumulated depreciation and amortization 750,507 733,977
---------- ----------
UTILITY PLANT - NET 1,266,104 1,195,899
---------- ----------
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
SFAS 109 regulatory asset - net 30,869 25,544
Unamortized loss on reacquired debt 14,224 15,122
Deferred fuel costs 22,468 95,661
Other regulatory assets 200 140,679
Other 7,715 5,886
---------- ----------
TOTAL 75,476 282,892
---------- ----------
TOTAL ASSETS $1,810,674 $1,683,939
========== ==========
See Notes to Financial Statements.
ENTERGY MISSISSIPPI, INC.
BALANCE SHEETS
LIABILITIES AND SHAREHOLDERS' EQUITY
September 30, 2001 and December 31, 2000
(Unaudited)
2001 2000
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt $65,000 $-
Accounts payable:
Associated companies 76,764 92,980
Other 29,022 26,933
Customer deposits 28,668 26,368
Taxes accrued 113,088 31,862
Accumulated deferred income taxes 33,552 47,734
Interest accrued 16,469 13,099
Obligations under capital leases 35 79
Other 19,807 2,540
---------- ----------
TOTAL 382,405 241,595
---------- ----------
DEFERRED CREDITS AND OTHER LIABILITIES
Accumulated deferred income taxes 261,581 306,295
Accumulated deferred investment tax credits 18,283 19,408
Obligations under capital leases 184 211
Accumulated provisions 2,706 6,806
Other 42,606 31,339
---------- ----------
TOTAL 325,360 364,059
---------- ----------
Long-term debt 589,675 584,467
SHAREHOLDERS' EQUITY
Preferred stock without sinking fund 50,381 50,381
Common stock, no par value, authorized 15,000,000
shares; issued and outstanding 8,666,357 in 2001 and 2000 199,326 199,326
Capital stock expense and other (59) (59)
Retained earnings 263,586 244,170
---------- ----------
TOTAL 513,234 493,818
---------- ----------
Commitments and Contingencies (Notes 1 and 2)
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $1,810,674 $1,683,939
========== ==========
See Notes to Financial Statements.
ENTERGY MISSISSIPPI, INC.
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2001 and 2000
(Unaudited)
Three Months Ended Increase/
Description 2001 2000 (Decrease) %
(In Millions)
Electric Operating Revenues:
Residential $ 147.6 $ 128.8 $ 18.8 15
Commercial 106.5 84.4 22.1 26
Industrial 55.8 43.4 12.4 29
Governmental 9.1 7.3 1.8 25
--------- --------- ------
Total retail 319.0 263.9 55.1 21
Sales for resale
Associated companies 26.9 27.9 (1.0) (4)
Non-associated companies 7.8 7.1 0.7 10
Other 0.8 (1.0) 1.8 180
--------- --------- ------
Total $ 354.5 $ 297.9 $ 56.6 19
========= ========= ======
Billed Electric Energy
Sales (GWH):
Residential 1,655 1,855 (200) (11)
Commercial 1,300 1,349 (49) (4)
Industrial 794 855 (61) (7)
Governmental 106 112 (6) (5)
--------- --------- ------
Total retail 3,855 4,171 (316) (8)
Sales for resale
Associated companies 423 355 68 19
Non-associated companies 117 105 12 11
--------- --------- ------
Total 4,395 4,631 (236) (5)
========= ========= ======
Nine Months Ended Increase/
Description 2001 2000 (Decrease) %
(In Millions)
Electric Operating Revenues:
Residential $ 317.6 $ 268.4 $ 49.2 18
Commercial 255.0 209.1 45.9 22
Industrial 146.3 120.0 26.3 22
Governmental 23.7 19.4 4.3 22
--------- --------- ------
Total retail 742.6 616.9 125.7 20
Sales for resale
Associated companies 109.6 40.9 68.7 168
Non-associated companies 17.4 20.8 (3.4) (16)
Other 15.2 17.7 (2.5) (14)
--------- --------- ------
Total $ 884.8 $ 696.3 $ 188.5 27
========= ========= =======
Billed Electric Energy
Sales (GWH):
Residential 3,907 3,890 17 -
Commercial 3,299 3,275 24 1
Industrial 2,279 2,384 (105) (4)
Governmental 289 281 8 3
--------- --------- ------
Total retail 9,774 9,830 (56) (1)
Sales for resale
Associated companies 1,755 561 1,194 213
Non-associated companies 225 244 (19) (8)
--------- --------- ------
Total 11,754 10,635 1,119 11
========= ========= ======
ENTERGY NEW ORLEANS, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Net Income (Loss)
Entergy New Orleans experienced a net loss for the three months ended
September 30, 2001, and experienced significantly lower net income for the
nine months ended September 30, 2001, primarily because of significantly
lower net revenue and increased other operation and maintenance and
interest expenses.
Revenues and Sales
Electric operating revenues
The changes in electric operating revenues for the three and nine
months ended September 30, 2001 are as follows:
Three Months Ended Nine Months Ended
Description Increase/(Decrease) Increase/(Decrease)
(In Millions)
Base rate changes ($4.6) ($8.3)
Fuel cost recovery 2.3 79.0
Sales volume/weather (8.1) (10.1)
Other revenue (including unbilled) (16.5) (12.3)
Sales for resale (3.6) (11.3)
------ -----
Total ($30.5) $37.0
====== =====
Base rate changes
Base rate changes decreased revenues for the three and nine months
ended September 30, 2001 primarily due to rate reductions that became
effective in October 2000.
Fuel cost recovery
Entergy New Orleans is allowed to recover certain fuel and purchased
power costs through fuel mechanisms included in electric rates, recorded
as fuel cost recovery revenues. The difference between revenues collected
and current fuel and purchased power costs is reflected as deferred fuel
costs on Entergy New Orleans' financial statements such that these costs
generally have no net effect on earnings.
Fuel cost recovery revenues increased for the nine months ended
September 30, 2001 primarily due to recovery through the fuel adjustment
clause of higher fuel and purchased power expenses. The increase in fuel
and purchased power expenses was a result of increased market prices of
natural gas and purchased power early in 2001.
Sales volume/weather
Lower electric sales volume reduced revenues for the three and nine
months ended September 30, 2001 due to decreased weather-adjusted usage of
83 GWH and 138 GWH, respectively, in the residential, commercial, and
governmental sectors. Electric sales vary seasonally in response to
weather and usually peak in the summer. Less favorable weather decreased
electric sales by 105 GWH and 108 GWH for the three and nine months ended
September 30, 2001, respectively, in the residential, commercial, and
governmental sectors.
ENTERGY NEW ORLEANS, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Other revenue (including unbilled)
Unbilled revenues decreased $13 million and $10 million for the three
and nine months ended September 30, 2001, respectively, primarily due to
the effects of lower fuel prices and less favorable weather for the period
included in the September 2001 unbilled revenue calculation compared to
the calculation in the prior year.
Sales for resale
Sales for resale decreased for the three and nine months ended
September 30, 2001 primarily due to a decrease in net generation resulting
in less energy available for sale. The decrease for the nine months ended
was partially offset by increased prices for resale electricity.
Gas operating revenues
Gas operating revenues increased for the nine months ended September
30, 2001 primarily due to the increased market price of natural gas and
increased sales due to a colder-than-normal winter. The increase in gas
revenues was largely offset by increased expenses for gas purchased for
resale.
Expenses
Fuel and purchased power
Fuel and purchased power expenses increased for the nine months
ended September 30, 2001 primarily due to the increased market prices of
natural gas and purchased power early in 2001.
Other operation and maintenance
Other operation and maintenance expenses increased for the three
months ended September 30, 2001 primarily due to increases in:
o plant maintenance of $1.7 million;
o vegetation maintenance spending of $1.4 million; and
o uncollectible receivable write-offs of $1.1 million.
Other operation and maintenance expenses increased for the nine
months ended September 30, 2001 primarily due to increases in:
o plant maintenance of $2.5 million;
o uncollectible receivable write-offs of $2.1 million; and
o increased customer service support costs of $1.4 million.
Taxes other than income taxes
Taxes other than income taxes increased for the nine months ended
September 30, 2001 primarily due to an increase in local franchise taxes
as a result of higher retail revenue.
ENTERGY NEW ORLEANS, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Amortization of rate deferrals
Amortization of rate deferrals decreased for the three and nine
months ended September 30, 2001 primarily due to a scheduled rate change
in the amortization of Grand Gulf 1 phase-in expenses. The Grand Gulf 1
phase-in plan was completed in September 2001.
Other
Interest and other charges
Interest on long-term debt increased for the nine months ended
September 30, 2001 primarily due to the issuance of $30 million of long-
term debt in July 2000 and the issuance of $30 million of long-term debt
in February 2001.
Income taxes
There was no effective income tax rate for the three months ended
September 30, 2001 as a result of the net loss generated. For the three
months ended September 30, 2000, the effective income tax rate was 40.7%.
For the nine months ended September 30, 2001 and 2000, the effective
income tax rates were 46.5% and 42.2%, respectively. The increase for the
nine months ended September 30, 2001 in the effective tax rate was
primarily due to the decrease in pre-tax income, which increased the
impact of flow-through items.
ENTERGY NEW ORLEANS, INC.
INCOME (LOSS) STATEMENTS
For the Three and Nine Months Ended September 30, 2001 and 2000
(Unaudited)
Three Months Ended Nine Months Ended
2001 2000 2001 2000
(In Thousands) (In Thousands)
OPERATING REVENUES
Domestic electric $154,462 $184,933 $422,751 $385,730
Natural gas 12,675 15,928 108,710 71,523
-------- -------- -------- --------
TOTAL 167,137 200,861 531,461 457,253
-------- -------- -------- --------
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale 46,139 60,389 206,826 142,421
Purchased power 74,067 61,197 181,393 135,091
Other operation and maintenance 24,575 20,277 67,151 59,934
Taxes other than income taxes 12,424 14,133 37,418 32,829
Depreciation and amortization 6,372 5,796 18,879 17,306
Other regulatory credits - net (3,721) (2,163) (7,427) (5,497)
Amortization of rate deferrals 4,628 9,096 10,977 21,573
-------- -------- -------- --------
TOTAL 164,484 168,725 515,217 403,657
-------- -------- -------- --------
OPERATING INCOME 2,653 32,136 16,244 53,596
-------- -------- -------- --------
OTHER INCOME
Allowance for equity funds used during construction 535 312 1,386 907
Miscellaneous - net 1,561 1,145 2,575 2,562
-------- -------- -------- --------
TOTAL 2,096 1,457 3,961 3,469
-------- -------- -------- --------
INTEREST AND OTHER CHARGES
Interest on long-term debt 4,661 3,840 13,229 10,479
Other interest - net 734 349 1,545 1,175
Allowance for borrowed funds used during construction (473) (239) (1,179) (684)
-------- -------- -------- --------
TOTAL 4,922 3,950 13,595 10,970
-------- -------- -------- --------
INCOME (LOSS) BEFORE INCOME TAXES (173) 29,643 6,610 46,095
Income taxes 135 12,050 3,073 19,468
-------- -------- -------- --------
NET INCOME (LOSS) (308) 17,593 3,537 26,627
Preferred dividend requirements and other 241 241 724 724
-------- -------- -------- --------
EARNINGS (LOSS) APPLICABLE TO
COMMON STOCK ($549) $17,352 $2,813 $25,903
======== ======== ======== ========
See Notes to Financial Statements.
ENTERGY NEW ORLEANS, INC.
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2001 and 2000
(Unaudited)
2001 2000
(In Thousands)
OPERATING ACTIVITIES
Net income $3,537 $26,627
Noncash items included in net income:
Amortization of rate deferrals 10,977 21,573
Reserve for regulatory adjustments (1,176) -
Other regulatory credits - net (7,427) (5,497)
Depreciation and amortization 18,879 17,306
Deferred income taxes and investment tax credits (43,474) 4,390
Allowance for equity funds used during construction (1,386) (907)
Changes in working capital:
Receivables (90,495) (56,406)
Fuel inventory 1,148 1,895
Accounts payable (21,707) 13,473
Taxes accrued 44,901 19,588
Interest accrued (3,145) (2,377)
Deferred fuel costs 30,616 (27,391)
Other working capital accounts 37,000 104
Provision for estimated losses and reserves (2,234) (900)
Changes in other regulatory assets 33,334 (7,777)
Other 7,806 6,544
-------- --------
Net cash flow provided by operating activities 17,154 10,245
-------- --------
INVESTING ACTIVITIES
Construction expenditures (44,286) (29,602)
Allowance for equity funds used during construction 1,386 907
Changes in other temporary investments - net (100) -
-------- --------
Net cash flow used in investing activities (43,000) (28,695)
-------- --------
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt 29,763 29,607
Dividends paid:
Common stock (800) (9,500)
Preferred stock (724) (482)
-------- --------
Net cash flow provided by financing activities 28,239 19,625
-------- --------
Net increase in cash and cash equivalents 2,393 1,175
Cash and cash equivalents at beginning of period 6,302 4,454
-------- --------
Cash and cash equivalents at end of period $8,695 $5,629
======== ========
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid/(received) during the period for:
Interest - net of amount capitalized $17,536 $13,747
Income taxes - ($2,368)
See Notes to Financial Statements.
ENTERGY NEW ORLEANS, INC.
BALANCE SHEETS
ASSETS
September 30, 2001 and December 31, 2000
(Unaudited)
2001 2000
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents $8,695 $6,302
Other temporary investments 100 -
Accounts receivable:
Customer 66,363 67,264
Allowance for doubtful accounts (770) (770)
Associated companies 90,686 2,800
Other 5,418 3,709
Accrued unbilled revenues 28,639 26,838
-------- --------
Total accounts receivable 190,336 99,841
-------- --------
Deferred fuel costs - 28,234
Accumulated deferred income taxes 9,888 -
Fuel inventory - at average cost 3,056 4,204
Materials and supplies - at average cost 7,861 9,630
Rate deferrals - 10,974
Prepayments and other 5,185 1,416
-------- --------
TOTAL 225,121 160,601
-------- --------
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity 3,259 3,259
-------- --------
UTILITY PLANT
Electric 579,576 572,061
Natural gas 141,062 134,826
Construction work in progress 57,881 36,489
-------- --------
TOTAL UTILITY PLANT 778,519 743,376
Less - accumulated depreciation and amortization 402,811 394,271
-------- --------
UTILITY PLANT - NET 375,708 349,105
-------- --------
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Unamortized loss on reacquired debt 814 974
Other regulatory assets 11,342 44,676
Other 2,149 616
-------- --------
TOTAL 14,305 46,266
-------- --------
TOTAL ASSETS $618,393 $559,231
======== ========
See Notes to Financial Statements.
ENTERGY NEW ORLEANS, INC.
BALANCE SHEETS
LIABILITIES AND SHAREHOLDERS' EQUITY
September 30, 2001 and December 31, 2000
(Unaudited)
2001 2000
(In Thousands)
CURRENT LIABILITIES
Accounts payable:
Associated companies $37,600 $24,637
Other 22,896 57,566
Customer deposits 18,709 18,311
Taxes accrued 50,724 5,823
Accumulated deferred income taxes - 6,543
Interest accrued 2,974 6,119
Deferred fuel cost 2,382 -
Other 41,813 3,211
-------- --------
TOTAL 177,098 122,210
-------- --------
DEFERRED CREDITS AND OTHER LIABILITIES
Accumulated deferred income taxes 14,776 43,754
Accumulated deferred investment tax credits 5,487 5,868
SFAS 109 regulatory liability - net 15,847 12,607
Other regulatory liabilities - 537
Accumulated provisions 6,237 8,471
Other 13,466 12,356
-------- --------
TOTAL 55,813 83,593
-------- --------
Long-term debt 229,072 199,031
SHAREHOLDERS' EQUITY
Preferred stock without sinking fund 19,780 19,780
Common stock, $4 par value, authorized 10,000,000 shares;
issued and outstanding 8,435,900 shares in 2001 and 2000 33,744 33,744
Paid-in capital 36,294 36,294
Retained earnings 66,592 64,579
-------- --------
TOTAL 156,410 154,397
-------- --------
Commitments and Contingencies (Notes 1 and 2)
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $618,393 $559,231
======== ========
See Notes to Financial Statements.
ENTERGY NEW ORLEANS, INC.
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2001 and 2000
(Unaudited)
Three Months Ended Increase/
Description 2001 2000 (Decrease) %
(In Millions)
Electric Operating Revenues:
Residential $ 70.2 $ 80.4 ($10.2) (13)
Commercial 53.8 55.4 (1.6) (3)
Industrial 8.9 7.6 1.3 17
Governmental 23.5 23.4 0.1 -
------ ------ -----
Total retail 156.4 166.8 (10.4) (6)
Sales for resale
Associated companies 0.7 3.9 (3.2) (82)
Non-associated companies 1.3 1.7 (0.4) (24)
Other (4.0) 12.5 (16.5) (132)
------ ------ -----
Total $ 154.4 $ 184.9 ($30.5) (16)
======= ======= ======
Billed Electric Energy
Sales (GWH):
Residential 721 851 (130) (15)
Commercial 633 676 (43) (6)
Industrial 117 103 14 14
Governmental 293 308 (15) (5)
------ ------ -----
Total retail 1,764 1,938 (174) (9)
Sales for resale
Associated companies 9 50 (41) (82)
Non-associated companies 21 25 (4) (16)
------ ------ -----
Total 1,794 2,013 (219) (11)
====== ====== =====
Nine Months Ended Increase/
Description 2001 2000 (Decrease) %
(In Millions)
Electric Operating Revenues:
Residential $ 157.0 $ 144.6 $ 12.4 9
Commercial 150.7 123.5 27.2 22
Industrial 25.7 17.7 8.0 45
Governmental 65.3 52.3 13.0 25
------ ------ -----
Total retail 398.7 338.1 60.6 18
Sales for resale
Associated companies 9.3 17.5 (8.2) (47)
Non-associated companies 3.0 6.1 (3.1) (51)
Other 11.7 24.0 (12.3) (51)
------ ------ -----
Total $ 422.7 $ 385.7 $ 37.0 10
======= ======= ======
Billed Electric Energy
Sales (GWH):
Residential 1,576 1,727 (151) (9)
Commercial 1,665 1,723 (58) (3)
Industrial 313 289 24 8
Governmental 768 805 (37) (5)
------ ------ -----
Total retail 4,322 4,544 (222) (5)
Sales for resale
Associated companies 99 351 (252) (72)
Non-associated companies 48 104 (56) (54)
------ ------ -----
Total 4,469 4,999 (530) (11)
====== ====== =====
SYSTEM ENERGY RESOURCES, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Net Income
Net income increased for the three and nine months ended September
30, 2001 compared to the three and nine months ended September 30, 2000
because of the final resolution of System Energy's 1995 rate proceeding
and the resulting reductions in decommissioning, depreciation, and income
tax expenses, partially offset by a decrease in revenue and an increase in
interest expense. See Note 2 to the financial statements for further
discussion of System Energy's rate proceeding.
Revenues
Operating revenues recover operating expenses, depreciation, and
capital costs attributable to Grand Gulf 1. Capital costs are computed by
allowing a return on System Energy's common equity funds allocable to its
net investment in Grand Gulf 1 and adding to such amount System Energy's
effective interest cost for its debt. Operating revenues decreased for
the three and nine months ended September 30, 2001 primarily due to an
increase in the provision for rate refund resulting from the final
resolution of System Energy's 1995 rate proceeding.
Expenses
Decommissioning
Decommissioning expenses decreased for the three and nine months
ended September 30, 2001 primarily due to the effects of the final FERC
order addressing System Energy's rate proceeding.
Depreciation and amortization
Depreciation and amortization expenses decreased for the three and
nine months ended September 30, 2001 primarily due to the effects of the
final FERC order addressing System Energy's rate proceeding.
Other regulatory charges
Other regulatory charges decreased for the three months ended
September 30, 2001 primarily due to the suspension of GGART recovery at
Entergy Arkansas in July 2001. The GGART is discussed in Note 2 to the
financial statements.
Other
Interest income
Interest income increased for the three and nine months ended
September 30, 2001 to recognize interest on decommissioning funds
resulting from the final FERC order addressing System Energy's rate
proceeding.
Interest expense
Interest on long-term debt decreased for the three and nine months
ended September 30, 2001 primarily due to a decrease in interest expense
associated with the sale-leaseback of Grand Gulf 1, decreased interest
expense on the sale-leaseback line of credit, and a decrease in interest
expense due to the retirement of $77.9 million in long-term debt in 2000
and 2001.
Other interest expense increased for the three and nine months ended
September 30, 2001 primarily due
to the effects of the final FERC order addressing System Energy's rate
proceeding.
SYSTEM ENERGY RESOURCES, INC.
MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS
RESULTS OF OPERATIONS
Income taxes
The effective income tax rates for the three months ended September
30, 2001 and 2000 were 0% and 47.3%, respectively. The effective income
tax rates for the nine months ended September 30, 2001 and 2000 were 30.6%
and 47.7%, respectively. The decreases in 2001 in the effective tax rates
were due to the effects of the final resolution of System Energy's 1995
rate proceeding.
SYSTEM ENERGY RESOURCES, INC.
INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2001 and 2000
(Unaudited)
Three Months Ended Nine Months Ended
2001 2000 2001 2000
(In Thousands) (In Thousands)
OPERATING REVENUES
Domestic electric $66,276 $169,114 $370,343 $485,592
------- -------- -------- --------
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and
gas purchased for resale 9,092 9,941 26,985 31,482
Nuclear refueling outage expenses 2,627 3,600 10,648 10,504
Other operation and maintenance 23,927 24,892 61,735 63,222
Decommissioning (26,738) 4,736 (17,266) 14,208
Taxes other than income taxes 6,177 7,094 19,345 19,262
Depreciation and amortization (44,435) 35,115 12,273 91,046
Other regulatory charges - net 11,720 16,156 50,842 46,952
------- -------- -------- --------
TOTAL (17,630) 101,534 164,562 276,676
------- -------- -------- --------
OPERATING INCOME 83,906 67,580 205,781 208,916
------- -------- -------- --------
OTHER INCOME
Allowance for equity funds used during construction 544 211 1,298 1,317
Miscellaneous - net 13,595 5,590 23,390 14,781
------- -------- -------- --------
TOTAL 14,139 5,801 24,688 16,098
------- -------- -------- --------
INTEREST AND OTHER CHARGES
Interest on long-term debt 16,032 20,420 53,799 67,183
Other interest - net 44,728 8,098 62,364 22,238
Allowance for borrowed funds used during construction (251) (113) (612) (766)
------- -------- -------- --------
TOTAL 60,509 28,405 115,551 88,655
------- -------- -------- --------
INCOME BEFORE INCOME TAXES 37,536 44,976 114,918 136,359
Income taxes (257) 21,267 35,125 65,078
------- -------- -------- --------
NET INCOME $37,793 $23,709 $79,793 $71,281
======= ======= ======= ========
See Notes to Financial Statements.
SYSTEM ENERGY RESOURCES, INC.
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2001 and 2000
(Unaudited)
2001 2000
(In Thousands)
OPERATING ACTIVITIES
Net income $79,793 $71,281
Noncash items included in net income:
Reserve for regulatory adjustments (322,368) 45,881
Other regulatory charges - net 50,842 46,952
Depreciation, amortization, and decommissioning (4,993) 105,254
Deferred income taxes and investment tax credits 115,981 (56,861)
Allowance for equity funds used during construction (1,298) (1,317)
Changes in working capital:
Receivables 10,421 154,032
Accounts payable 516,329 (12,045)
Taxes accrued (68,530) 11,721
Interest accrued (15,704) (9,899)
Other working capital accounts (30,088) 16,486
Provision for estimated losses and reserves (665) (203)
Changes in other regulatory assets 10,929 37,386
Other (18,502) (36,423)
-------- --------
Net cash flow provided by operating activities 322,147 372,245
-------- --------
INVESTING ACTIVITIES
Construction expenditures (29,840) (28,148)
Allowance for equity funds used during construction 1,298 1,317
Nuclear fuel purchases (37,639) (7)
Proceeds from sale/leaseback of nuclear fuel 37,639 7
Decommissioning trust contributions and realized
change in trust assets (14,639) (17,368)
Changes in other temporary investments - net (153,157) -
-------- --------
Net cash flow used in investing activities (196,338) (44,199)
-------- --------
FINANCING ACTIVITIES
Retirement of long-term debt (151,800) (47,947)
Dividends paid:
Common stock (65,800) (71,700)
-------- --------
Net cash flow used in financing activities (217,600) (119,647)
-------- --------
Net increase (decrease) in cash and cash equivalents (91,791) 208,399
Cash and cash equivalents at beginning of period 202,218 35,152
-------- --------
Cash and cash equivalents at end of period $110,427 $243,551
======== ========
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized $128,588 $72,049
Income taxes $3,463 $104,042
Noncash investing and financing activities:
Change in unrealized appreciation/(depreciation) of
decommissioning trust assets ($6,667) $4,988
See Notes to Financial Statements.
SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
ASSETS
September 30, 2001 and December 31, 2000
(Unaudited)
2001 2000
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash $98 $44
Temporary cash investments - at cost,
which approximates market 110,329 202,174
---------- ----------
Total cash and cash equivalents 110,427 202,218
---------- ----------
Other temporary investments 153,157 -
Accounts receivable:
Associated companies 202,632 212,551
Other 1,692 2,194
---------- ----------
Total accounts receivable 204,324 214,745
---------- ----------
Materials and supplies - at average cost 51,944 52,235
Deferred nuclear refueling outage costs 11,356 6,577
Prepayments and other 28,243 2,639
---------- ----------
TOTAL 559,451 478,414
---------- ----------
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds 165,544 157,572
---------- ----------
UTILITY PLANT
Electric 3,100,564 3,093,033
Property under capital lease 449,851 449,851
Construction work in progress 39,167 24,029
Nuclear fuel under capital lease 68,907 49,256
---------- ----------
TOTAL UTILITY PLANT 3,658,489 3,616,169
Less - accumulated depreciation and amortization 1,404,296 1,407,885
---------- ----------
UTILITY PLANT - NET 2,254,193 2,208,284
---------- ----------
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
SFAS 109 regulatory asset - net 189,475 195,634
Unamortized loss on reacquired debt 49,275 51,957
Other regulatory assets 169,747 174,517
Other 8,584 8,172
---------- ----------
TOTAL 417,081 430,280
---------- ----------
TOTAL ASSETS $3,396,269 $3,274,550
========== ==========
See Notes to Financial Statements.
SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
LIABILITIES AND SHAREHOLDER'S EQUITY
September 30, 2001 and December 31, 2000
(Unaudited)
2001 2000
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt $47,691 $151,800
Accounts payable:
Associated companies 521,993 2,722
Other 20,643 23,585
Taxes accrued - 68,530
Accumulated deferred income taxes 3,505 1,648
Interest accrued 28,303 44,007
Obligations under capital leases 32,119 32,119
Other 1,679 1,674
---------- ----------
TOTAL 655,933 326,085
---------- ----------
DEFERRED CREDITS AND OTHER LIABILITIES
Accumulated deferred income taxes 518,407 391,505
Accumulated deferred investment tax credits 86,909 89,516
Obligations under capital leases 36,788 17,137
FERC settlement - refund obligation 25,234 30,745
Other regulatory liabilities 139,095 103,634
Decommissioning 126,607 153,197
Regulatory reserves - 322,368
Accumulated provisions 24 689
Other 16,634 15,394
---------- ----------
TOTAL 949,698 1,124,185
---------- ----------
Long-term debt 883,219 930,854
SHAREHOLDER'S EQUITY
Common stock, no par value, authorized 1,000,000 shares;
issued and outstanding 789,350 shares in 2001 and 2000 789,350 789,350
Retained earnings 118,069 104,076
---------- ----------
TOTAL 907,419 893,426
---------- ----------
Commitments and Contingencies (Notes 1 and 2)
TOTAL LIABILITIES AND SHAREHOLDER'S EQUITY $3,396,269 $3,274,550
========== ==========
See Notes to Financial Statements.
ENTERGY CORPORATION AND SUBSIDIARIES
NOTES TO FINANCIAL STATEMENTS
(Unaudited)
NOTE 1. COMMITMENTS AND CONTINGENCIES
Capital Requirements and Financing (Entergy Corporation, Entergy
Arkansas, Entergy Gulf States, Entergy Louisiana, Entergy Mississippi,
Entergy New Orleans, and System Energy)
See Note 9 to the financial statements in the Form 10-K for
information on Entergy's estimated construction expenditures (including
nuclear fuel but excluding AFUDC), long-term debt and preferred stock
maturities, and cash sinking fund requirements.
Sales Warranties and Indemnities (Entergy Corporation)
In the Entergy London and CitiPower sales transactions, Entergy or
its subsidiaries made certain warranties to the purchasers. These
warranties include representations regarding litigation, accuracy of
financial accounts, and the adequacy of existing tax provisions. Notice
of a claim on the CitiPower warranties had to be given by December 2000,
and Entergy's potential liability is limited to A$100 million ($49
million). Notice of a claim on the Entergy London warranties had to be
given for certain items by December 1999, and for the tax warranties, had
to be given by June 30, 2001. Entergy's liability is limited to BPS1.4
billion ($2.0 billion) on certain tax warranties and BPS140 million
($200 million) on the remaining warranties relating to the Entergy London
sale. Entergy also agreed to maintain the net asset value of the
subsidiary that sold Entergy London at $700 million through June 30, 2001.
For both of the sales, the notice period is extended if a taxing
authority has begun a review before expiration of the notice period.
Entergy received notice in June 2001 from both purchasers regarding issues
that have not been resolved by the respective taxing authorities
concerning reviews that commenced before the notice deadlines. Entergy
responded to both purchasers and denies that valid claims by the
purchasers have been made under the warranties. Management periodically
reviews reserve levels for these warranties and as of September 30, 2001
believes it has adequately provided for the ultimate resolution of these
matters.
Nuclear Insurance, Spent Nuclear Fuel, and Decommissioning Costs
(Entergy Corporation, Entergy Arkansas, Entergy Gulf States, Entergy
Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)
See Note 9 to the financial statements in the Form 10-K for
information on nuclear liability, property and replacement power
insurance, related NRC regulations, the disposal of spent nuclear fuel,
other high-level radioactive waste, and decommissioning costs associated
with ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf 1, Pilgrim, Indian
Point 3, and FitzPatrick. Regarding the property damage and replacement
power insurance programs, a proposed revision is currently pending
approval by the members that provides for sharing among the members of
limits up to $3.24 billion for all terrorist loss among the members that
might be incurred within one year. If the proposal is approved, it could
become effective as early as November 15, 2001.
Entergy purchased the Indian Point 1 and Indian Point 2 nuclear power
plants in September 2001 from Consolidated Edison. Indian Point 1 has been
shut down and in safe storage since the early 1970s. Entergy's domestic
non-utility nuclear business has accepted assignment of the Indian Point 2
spent fuel disposal contract with the DOE previously held by Consolidated
Edison. Consolidated Edison has paid or retained liability for the DOE
fees for all generation prior to the purchase date of Indian Point 2.
Indian Point 2 currently has sufficient spent fuel storage capacity until
approximately 2004.
As part of the Indian Point 1 and 2 purchase, Consolidated Edison
transferred a $430 million decommissioning trust fund, along with the
liability to decommission Indian Point 2 and Indian Point 1, to Entergy's
domestic non-utility nuclear business. Entergy also funded an additional
$25 million resulting in a total fund of $455 million at September 30,
2001. Entergy believes that Indian Point 1 and 2's decommissioning fund
will be adequate to cover future decommissioning costs for these plants
without any additional deposits to the trust.
Environmental Issues
(Entergy Arkansas)
In previous years, Entergy Arkansas has received notices from the EPA
and the Arkansas Department of Environmental Quality (ADEQ) alleging that
Entergy Arkansas, along with others, may be a potentially responsible
party (PRP) for clean-up costs associated with a site in Arkansas. As of
September 30, 2001, a remaining recorded liability of approximately $5.0
million existed related to the cleanup of that site.
(Entergy Gulf States)
Entergy Gulf States has been designated as a PRP for the cleanup of
certain hazardous waste disposal sites. Entergy Gulf States is currently
negotiating with the EPA and state authorities regarding the cleanup of
these sites. As of September 30, 2001, a remaining recorded liability of
approximately $15.4 million existed related to the cleanup of the
remaining sites at which the EPA has designated Entergy Gulf States as a
PRP.
(Entergy Louisiana and Entergy New Orleans)
During 1993, the LDEQ issued new rules for solid waste regulation,
including regulation of wastewater impoundments. Entergy Louisiana and
Entergy New Orleans have determined that certain of their power plant
wastewater impoundments were affected by these regulations and have chosen
to upgrade or close them. Recorded liabilities in the amounts of
$5.8 million for Entergy Louisiana and $0.5 million for Entergy New
Orleans existed at September 30, 2001 for wastewater upgrades and
closures. Completion of this work is awaiting LDEQ approval.
City Franchise Ordinances (Entergy New Orleans)
Entergy New Orleans provides electric and gas service in the City of
New Orleans pursuant to franchise ordinances. These ordinances contain a
continuing option for the City to purchase Entergy New Orleans' electric
and gas utility properties.
Waterford 3 Lease Obligations (Entergy Louisiana)
On September 28, 1989, Entergy Louisiana entered into three separate
but substantially identical transactions for the sale and leaseback of
undivided interests (aggregating approximately 9.3%) in Waterford 3, which
were refinanced in 1997. Upon the occurrence of certain events, Entergy
Louisiana may be obligated to pay amounts sufficient to permit the Owner
Participants to withdraw from these lease transactions and may be required
to assume the outstanding bonds issued to finance, in part, the lessors'
acquisition of the undivided interests in Waterford 3. See Note 10 to the
financial statements in the Form 10-K for further information.
Employment Litigation (Entergy Corporation, Entergy Gulf States, Entergy
Louisiana, and Entergy Mississippi)
Entergy Corporation, Entergy Gulf States, Entergy Louisiana, and
Entergy Mississippi are defendants in numerous lawsuits filed by former
employees asserting that they were wrongfully terminated and/or
discriminated against on the basis of age, race, and/or sex. The
defendant companies are vigorously defending these suits and deny any
liability to the plaintiffs. However, no assurance can be given as to the
outcome of these cases.
Reimbursement Agreement (System Energy)
Under a bank letter of credit and reimbursement agreement, System
Energy has agreed to a number of covenants relating to the maintenance of
certain capitalization and fixed charge coverage ratios. System Energy
agreed, during the term of the agreement, to maintain its equity at not
less than 33% of its adjusted capitalization (defined in the agreement to
include certain amounts not included in capitalization for financial
statement purposes). In addition, System Energy must maintain, with
respect to each fiscal quarter during the term of the agreement, a ratio
of adjusted net income to interest expense (calculated, in each case, as
specified in the agreement) of at least 1.60 times earnings. System
Energy was in compliance with the above covenants at September 30, 2001.
See Note 9 to the financial statements in the Form 10-K for further
information.
Litigation (Entergy Corporation, Entergy Arkansas, Entergy Gulf States,
Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans)
In addition to those proceedings discussed elsewhere herein and in
the Form 10-K, Entergy and the domestic utility companies are involved in
a number of other legal proceedings and claims in the ordinary course of
their businesses. While management is unable to predict the outcome of
these other legal proceedings and claims, it is not expected that their
ultimate resolution individually or collectively will have a material
adverse effect on the results of operations, cash flows, or financial
condition of these entities.
NOTE 2. RATE AND REGULATORY MATTERS
Electric Industry Restructuring
Previous developments and information related to electric industry
restructuring are presented in Note 2 to the financial statements in the
Form 10-K.
Arkansas (Entergy Corporation and Entergy Arkansas)
As discussed in Note 2 to the financial statements in the Form 10-K,
the target date for retail open access has been delayed until no sooner
than October 1, 2003 and no later than October 1, 2005.
In October 2000, in compliance with the currently enacted
deregulation law, Entergy Arkansas filed a market power study in
accordance with the guidelines adopted by the APSC. In December 2000,
Entergy Arkansas filed an application for approval to transfer Entergy
Arkansas' transmission assets to the Transco. In February 2001, Entergy
Arkansas filed supplemental testimony to address the effects of the
proposed Transco on Entergy Arkansas' market power. In July 2001, Entergy
Arkansas filed a request, which the APSC approved, to suspend proceedings
regarding Transco pending further action in the FERC-mandated mediation
proceedings.
In September 2001, the APSC staff issued a report recommending the
following:
o the APSC use its statutory authority to delay retail open access
until October 1, 2004;
o the APSC recommend to the Arkansas General Assembly that legislation
be enacted to further delay or repeal retail open access, with repeal
as the better approach; and
o further suspension of all rulemaking activity to implement retail
open access.
Entergy Arkansas agreed in reply testimony to the proposed further delay
of retail open access but opposed repeal of deregulation legislation as
premature at this time. A hearing is currently scheduled for November
2001.
Texas (Entergy Corporation and Entergy Gulf States)
As discussed in Note 2 to the financial statements in the Form 10-K,
the Texas legislature enacted a law providing for retail open access by
most investor-owned electric utilities, including Entergy Gulf States, on
January 1, 2002, unless delayed by the PUCT. On August 3, 2001, the PUCT
staff filed a petition requesting that the PUCT determine whether the
market is ready for retail open access in the portion of Texas within the
Southeastern Electric Reliability Council (SERC), which includes Entergy
Gulf States' service territory. In its petition, the PUCT staff states
that the retail electric power pilot project in SERC has not been
successful to date in creating competition. The petition also states
that, in light of information received by the PUCT staff indicating a lack
of interest in SERC by the retail electric provider community at this time
and the uncertainty surrounding the status of an RTO in SERC, it is
unlikely that the competitive situation in SERC will improve to any
significant degree before the current date for full customer choice to
begin in SERC. Certain cities served by Entergy Gulf States also filed a
petition asking the PUCT to delay competition for Entergy Gulf States.
Several parties, including Entergy Gulf States and the PUCT staff, agreed
to a non-unanimous settlement that was filed with the PUCT on October 22,
2001. A hearing was held before the PUCT on October 31, 2001 at which
time the PUCT voted to approve the settlement. The settlement agreement
contains several points, including:
o a delay in the commencement of retail open access until at least
September 15, 2002, subject to certain provisions of the settlement
agreement;
o suspension of additional capacity auctions until at least sixty days
before retail open access commences (the capacity auctions are
discussed below);
o continuation of Entergy Gulf States' current pilot project;
o initiation by the PUCT of a project to develop market protocols to
support retail open access;
o efforts to develop an interim solution to implement retail open
access no sooner than September 15, 2002 in the event that a
functional, FERC-approved RTO is not likely to be achieved in the
2002 time frame (the RTO and related power region certification
issue are discussed below);
o going forward with the currently pending proceedings (discussed
below) to determine the fuel and base rate components of the
price-to-beat rates with implementation of these rates when retail
open access begins, without escalation of the fuel component during
the delay period;
o continuation of Entergy Gulf States' current bundled rates and fuel
factor methodology until the commencement of retail open access unless
addressed in the interim solution; and
o continuation of efforts by Entergy Gulf States to obtain the
appropriate approvals with respect to its business separation plan
(discussed below) with the actual business separation not occurring
until the eve of retail open access.
Business Separation Plan
Entergy Gulf States' business separation plan provides for the
separation of its generation, transmission, distribution and retail
electric functions. It has been amended during the course of various PUCT
and LPSC proceedings and is subject to further change and regulatory
proceedings as described below.
The amended plan currently provides that Entergy Gulf States will be
separated into the following principal companies:
o a Texas distribution company, which will own and operate Entergy Gulf
States' electric distribution system in Texas;
o a Texas generation company (which may be more than one legal entity),
which initially will purchase capacity and energy from the generating
assets allocated to Texas load (Texas generating assets), and eventually
will own those assets;
o Texas retail electric providers, which will provide competitive
retail electric service in Texas; and
o Entergy Gulf States-Louisiana.
Entergy Gulf States-Louisiana will:
o own and operate Entergy Gulf States' electric distribution system in
Louisiana, the Texas generating assets (until they are transferred to
the Texas generation company), the remainder of Entergy Gulf States'
generating assets, and Entergy Gulf States' other businesses that are not
separated, and own Entergy Gulf States' transmission assets allocated to
Louisiana (until they are transferred to the intermediate transmission
company described in the next bullet); and
o indirectly own a portion of an intermediate transmission company,
which will own Entergy Gulf States' electric transmission assets
allocated to Texas, and later Entergy Gulf States' transmission
assets allocated to Louisiana.
Entergy Gulf States' assets and liabilities (other than its long-term
debt and liabilities) will be allocated among these companies generally
based upon categorizing them by function. Entergy Gulf States will
allocate assets and liabilities not associated with a single function
based upon specified factors. In an April 2001 filing with the LPSC
discussing its separation methodology, Entergy Gulf States included a
balance sheet separated by jurisdiction and function. The balance sheet
was based on September 30, 1999 balances. In this balance sheet, Entergy
Gulf States allocated approximately 27% of the net utility plant balance
to Texas generation, approximately 12% to Texas distribution,
approximately 6% to Texas transmission, approximately 7% to Louisiana
transmission, and less than 1% to Texas retail. Applying these
percentages to Entergy Gulf States' September 30, 2001 net utility plant
book value of $4.3 billion, for illustrative purposes only, results in net
book values of approximately $1.2 billion for Texas generation,
approximately $580 million for Texas distribution, approximately $180
million for Texas transmission, approximately $210 million for Louisiana
transmission, approximately $20 million for Texas retail, and
approximately $2.1 billion for the remainder of Entergy Gulf States-
Louisiana. The actual allocations could materially differ from these
figures because of a number of factors, including changes to the plan and
the allocation methodology. In addition, the actual allocations will be
based on allocation factors and account balances as of a different date.
The business separation plan provides that Entergy Gulf States-
Louisiana will retain liability for all of its long-term debt and
liabilities and that the property transferred to the Texas companies will
be released from the lien of Entergy Gulf States' mortgage on the basis of
property additions. Pursuant to separate agreements, the Texas
distribution company and the intermediate transmission company will each
assume a portion of Entergy Gulf States' long-term debt and liabilities,
which assumptions will not act to release Entergy Gulf States-Louisiana's
liability. The Texas distribution company and the intermediate
transmission company will undertake to pay the outstanding assumed long-
term debt and liabilities within 1 year and 3 years, respectively, of the
assumption. Entergy must provide a contingent indemnity with respect to
the intermediate transmission company's assumed portion of Entergy Gulf
States' long-term debt and liabilities in the event that the obligations
under the debt assumption agreement have not been extinguished within one
year of the assumption. The Texas generation company will be required to
pay an allocated portion of the outstanding principal amount of Entergy
Gulf States' long-term debt and liabilities each time that Texas
generating assets are transferred to it, and the transfers must be
completed within 3 years of the commencement of retail open access.
After the transfer of the Texas distribution and transmission assets
contemplated by the current business separation plan, the distribution and
transmission businesses conducted by the Texas distribution company and
the intermediate transmission company, respectively, will continue to be
regulated as to rates by the PUCT and the FERC, respectively.
Accordingly, management believes that the Texas distribution company and
the intermediate transmission company will be able to fund the payment of
the assumed debt within the required period from a combination of cash
flow from operations and third party financing.
Entergy Gulf States filed the business separation plan with the PUCT
in January 2000 and amended that plan in November 2000 and January 2001.
In May 2001, the PUCT approved the amended business separation plan in an
interim order. The outcome of the LPSC proceedings described below, which
have resulted in amendments to the plan beyond what was approved by the
PUCT, will be reported to the PUCT and the Office of Public Utility
Counsel and may require additional PUCT action before the business
separation plan is final. In addition, the proceeding described above
that has delayed the commencement of retail open access may affect the
approval.
The LPSC opened a docket to identify the changes in corporate
structure and operations of Entergy Gulf States, and their potential
impact on Louisiana retail ratepayers, resulting from restructuring in
Texas and Arkansas. In those proceedings, Entergy Gulf States and the
LPSC staff reached a settlement on certain Texas business separation plan
issues described above, and after a May 2001 hearing, the LPSC issued an
interim order in July 2001 approving the settlement. In July 2001,
Entergy Gulf States and the LPSC staff completed an additional settlement
on business separation plan issues relating to the separation of Texas
distribution and transmission. A hearing on the distribution and
transmission settlement has been held and the LPSC approved the settlement
in September 2001. With respect to issues related to the separation of
generation, the LPSC scheduled a hearing in November 2001 to address
settled issues. In light of the delay in the commencement of retail open
access, the procedural schedule in the LPSC docket has been temporarily
suspended to assess the impact of the PUCT decision.
Generation-related Issues
Regarding the generation-related issues referred to in the preceding
paragraph, Entergy Gulf States has not yet reached agreement with the LPSC
staff on certain matters related to the separation of the Texas generating
assets. Entergy Gulf States has proposed that Texas generating assets be
a jurisdictional portion (approximately 45 - 50%) of each generating plant
and that Entergy Gulf States-Louisiana continue to operate the plants.
Entergy Gulf States has also suggested that certain generating assets be
allocated by specific plant such that the Texas generating assets have
approximately the Texas jurisdictional portion of the capacity and value
of all of Entergy Gulf States' generating assets.
Until the Texas generating assets are transferred to the Texas
generation company, which, as currently proposed, will occur by the end of
2004, Entergy Gulf States-Louisiana expects to sell most of the Texas
jurisdictional capacity and energy from these assets to the Texas
generation company under a power sale agreement. The power sale
agreement is expected to require the Texas generation company to pay all
costs, including a reasonable return on equity, for the capacity and
energy of the Texas generating assets. The Texas generation company is
expected to sell most of this capacity and energy to Entergy's affiliated
Texas retail electric providers at a negotiated rate and sell any
remainder to the market. Entergy's affiliated Texas retail electric
providers will use the capacity and energy to provide retail electric
service to retail customers in Texas, including Entergy's "price-to-beat"
obligation, which requires it to sell electricity to residential and small
commercial customers in the service territory of the Texas distribution
company at a rate equal to the existing base rates plus a fuel component.
Up to 20% of capacity and energy from the Texas generating assets
must be sold to third parties under PUCT rules, or to Entergy's domestic
utility companies that elect to purchase it, as described below:
o Under the Texas restructuring legislation and a stipulation, Entergy
Gulf States offered to sell at auction entitlements to approximately 425
megawatts of its installed generation capacity in Texas. Auctions
occurred in September 2001, and not all of the entitlements offered at
auction sold. The settlement that delayed retail open access provides
for suspension of additional capacity auctions until at least 60 days
prior to the introduction of retail open access. The obligation to
auction capacity entitlements continues for up to 60 months after
retail open access occurs, or until 40% of current customers have
chosen an alternative supplier, whichever comes first.
o Under the settlement of System Agreement proceedings, which are
described in "MANAGEMENT'S FINANCIAL DISCUSSION AND ANALYSIS -
SIGNIFICANT FACTORS AND KNOWN TRENDS", Entergy's domestic utility
companies have the option to purchase up to 5% of the megawatt
capacity of the Texas generating assets. Each company has until
December 2001 to elect to purchase its pro rata share of this
capacity. If the capacity purchase is elected, it will be for the
period from the inception of retail open access in Texas for Entergy
Gulf States through June 2008.
Beginning on the date retail open access begins, the market power
measures in the Texas restructuring law will prohibit the Texas generation
company and its affiliates from owning and controlling more than 20% of
the installed generation capacity located in, or capable of delivering
electricity to, a power region. The implications of this limit are
uncertain. It is possible that the Texas generation company (or its
affiliates) could be required to auction additional capacity entitlements,
divest some of the Texas generating assets, or seek other means of
mitigation if it is found to have ownership in excess of this limit.
Other PUCT Proceedings
In March 2001, Entergy Gulf States filed with the PUCT a non-
unanimous settlement agreement in its unbundled cost of service proceeding
that establishes the Texas distribution company's revenue requirement.
The settlement agreement is among Entergy Gulf States, the PUCT staff, and
other parties. Pursuant to a generic rule prescribed by the PUCT, the
Texas distribution company's allowed return on equity will be 11.25%. The
capital structure prescribed by the PUCT is 60% debt and 40% equity. A
rider to recover nuclear decommissioning costs will be implemented. Also
in the settlement agreement, the parties agree that Entergy Gulf States'
Texas jurisdictional stranded costs and benefits are $0, and no charge to
recover stranded costs or credit to refund excess mitigation will be
implemented. Nevertheless, if new legislation passes in Texas that
requires or expressly authorizes the PUCT to require Entergy Gulf States
to pass-through or share stranded benefits with its customers, that
legislation will control this issue. Entergy Gulf States agreed in the
settlement to refund any excess earnings resulting from the restructuring
law's annual report process for 2000 and 2001. After a hearing in April
2001, the PUCT voted to approve a rate order consistent with the terms of
the settlement. A written interim order was signed in May 2001. In
October 2001, the PUCT indicated its intent to defer a final ruling on
this proceeding until a date closer to opening the market to retail open
access.
In June 2001, Entergy filed an application with the PUCT seeking
certification of the Southwest Power Pool (SPP) as a power region under
the Texas restructuring law. The proceeding has been abated, however, due
to FERC's order on the establishment of regional transmission
organizations (RTOs), discussed in "MANAGEMENT'S FINANCIAL DISCUSSION AND
ANALYSIS - SIGNIFICANT FACTORS AND KNOWN TRENDS". In addition, the
settlement that has delayed the commencement of retail open access
requires a new power region certification proceeding. If Entergy Gulf
States' power region in Texas is not certified by the PUCT before retail
open access is introduced, Entergy's affiliated Texas retail electric
provider could be required to maintain rates at the price-to-beat levels
for residential and small commercial customers in Entergy Gulf States'
service territory beyond January 1, 2007. Entergy's affiliated Texas
retail electric provider could also be required to offer rates to
industrial and large commercial customers in Entergy Gulf States' service
territory that are no higher than the rates that, on a bundled basis, were
in effect on January 1, 1999, subject to fuel factor adjustments.
Entergy's affiliated Texas retail electric provider might also face
requests for restrictions in its ability to compete for retail customers
in parts of its power region in Texas outside of its current service area.
In July 2001, Entergy Gulf States filed an application for approval
of the fuel factor portion of Entergy's affiliated Texas retail electric
provider's price-to-beat rates, and the gas price was updated in October
2001. After the gas price update, Entergy Gulf States is recommending
that the PUCT approve an average fuel factor of approximately $29/MWH
adjusted, if necessary, to maintain an adequate competitive margin. The
request proceeded to hearing in early October 2001, and an ALJ made a
recommendation in November 2001 that would result in a lower factor. A
PUCT decision is expected by December 2001. In June 2001, Entergy Gulf
States filed tariffs for the non-fuel component of the price-to-beat
rates. The tariffs are based on Entergy Gulf States' current base rates.
In September 2001, Entergy Gulf States entered into a unanimous
settlement. A final decision from the PUCT is expected in November 2001.
The PUCT had designated an Entergy-affiliated Texas retail electric
provider to serve as the provider of last resort (POLR) for residential
and small non-residential customers in the service territory of
Southwestern Electric Power Company (SWEPCO), and for industrial and large
commercial customers in Entergy Gulf States' Texas service territory.
Retail open access has been delayed in SWEPCO's service territory, and
Entergy's contract to provide POLR services will expire before retail open
access begins there. Another designation of a POLR in that territory will
be necessary if retail open access is implemented there. The PUCT has
designated SWEPCO's affiliated retail electric provider as the POLR for
the residential and small non-residential customers in Entergy Gulf
States' Texas service territory. Retail competition in Entergy Gulf
States' Texas service territory has been delayed until at least September
15, 2002, and it will not be necessary for SWEPCO's retail electric
provider to provide POLR service in the service territory under the
contract that has been negotiated until retail open access begins. If
retail open access does not begin in the Entergy Gulf States service
territory in 2002, SWEPCO's contract to provide POLR service will likely
expire, and another retail electric provider will have to be designated to
serve as the POLR when retail open access does begin. At that time, it is
also possible that an Entergy-affiliated Texas retail electric provider
will be designated to serve as the POLR for residential and small non-
residential customers at the price-to-beat rate in the service territory.
Neither the timing nor the outcome of these proceedings can be predicted
at this time.
Other Regulatory Proceedings and Uncertainties
In addition to the PUCT and LPSC proceedings relating to the business
separation plan described above, certain aspects of the business
separation plan will also have to be approved by the SEC under PUHCA.
Entergy Gulf States filed an application for SEC approval in August 2001.
In addition, as discussed in "MANAGEMENT'S FINANCIAL DISCUSSION AND
ANALYSIS - SIGNIFICANT FACTORS AND KNOWN TRENDS", FERC has approved a
settlement providing for certain amendments to the System Agreement
required by the Texas restructuring. Certain aspects of the Texas
restructuring will require additional FERC approvals. Entergy Gulf States
will also have to obtain the approval of the NRC if it transfers ownership
of any interest in River Bend.
The regulatory proceedings described above have affected, and are
likely to continue to affect, the final form and timing of implementation
of the business separation plan. It is possible that these approvals or
related regulatory orders
o may not be received in time to implement the plan on the date retail
open access is scheduled to begin;
o may be obtained with requirements or conditions that differ from the
business separation plan described above or that conflict with each
other; or
o may be obtained with conditions that are unacceptable to Entergy or
that do not permit timely implementation.
Entergy Gulf States' business separation plan has already been amended
during the course of the PUCT and LPSC proceedings described above and is
subject to further change as a result of the regulatory approval process
or otherwise. As a result, no assurance can be given that the business
separation plan will be implemented as described above or that it will not
change significantly before implementation.
Louisiana (Entergy Corporation and Entergy Louisiana)
As discussed in Note 2 to the financial statements in the Form 10-K,
the LPSC directed the LPSC staff, outside consultants, and counsel to
work together to analyze and resolve issues related to competition and to
recommend a plan for consideration by the LPSC. In July 2001, the LPSC
staff submitted a final response to the LPSC. In its report the LPSC
staff concluded that retail competition is not in the public interest at
this time for any customer class. Nevertheless, the LPSC staff
recommended that retail open access be made available for certain large
industrial customers as early as January 2003. An eligible customer
choosing to go to competition would be required to provide its utility
with a minimum of six months notice prior to the date of retail open
access. The LPSC staff report also recommended that all customers who do
not currently co- or self-generate, or have co- or self-generation under
construction as of a date to be specified by the LPSC, remain liable for
their share of stranded costs. During its October 2001 meeting, the LPSC
adopted dates by which a total of 800 MW of co- or self-generation could
be developed in Louisiana without being affected by stranded costs.
During its November 2001 meeting, the LPSC decided not to adopt a plan for
retail open access at this time, but to have collaborative group meetings
concerning open access from time to time, and to have the LPSC staff
monitor developments in neighboring states and to report to the LPSC
regarding the progress of retail access developments in those states. At
this time, no further moves toward retail access in Louisiana appear
likely until sometime during or after 2004.
Retail Rate Proceedings
Previous developments and information related to retail rate
proceedings are presented in Note 2 to the financial statements in the
Form 10-K.
Filings with the APSC (Entergy Corporation and Entergy Arkansas)
In March 2001, Entergy Arkansas filed its annually redetermined
energy cost rate with the APSC in accordance with the energy cost rate
formula, including a new energy allocation factor. The filing reflected
that an increase was warranted due to the increase in fuel and purchased
power costs in 2000 and the accumulated under-recovery of 2000 energy
costs. The increased energy cost rate is effective April 2001 through
March 2002.
As discussed in Note 2 to the financial statements in the Form 10-K,
Entergy Arkansas is operating under the terms of a settlement agreement
approved by the APSC that allows the collection of excess earnings in a
transition cost account. Upon recommendation from the APSC, Entergy
Arkansas recorded an adjustment for 2000 excess earnings in the transition
cost account of $10.9 million ($6.7 million after tax) in June 2001 and
$7.9 million ($4.8 million after tax) in September 2001. Interest of $4.6
million ($2.8 million after tax) was also recorded in the transition cost
account for the first nine months of 2001.
December 2000 Ice Storms
In mid- and late December 2000, two separate ice storms left 226,000
and 212,500 Entergy Arkansas customers, respectively, without electric
power in its service area. The storms were the most severe natural
disasters ever to affect Entergy Arkansas, causing damage to transmission
and distribution lines, equipment, poles, and facilities. In April 2001,
Entergy Arkansas filed with the APSC a proposal to recover, over
approximately a five and one-half year period, costs plus carrying charges
associated with power restoration caused by the December 2000 ice storms.
In an order issued in June 2001, the APSC decided not to give final
approval to Entergy's proposed storm cost recovery rider outside of a
fully developed cost-of-service study in a general rate proceeding. The
APSC action resulted in the deferral in 2001 of previously expensed storm
damage costs as reflected in Entergy Arkansas' financial statements. In a
subsequent decision, the APSC ordered Entergy Arkansas to commence such a
proceeding by January 2002.
In the subsequent order, the APSC also established a procedural
schedule to consider putting an interim rider in place to recover the ice
storm costs, subject to refund. The schedule calls for a January 2002
hearing date and the issuance of a decision by February 2002. In accord
with the schedule, Entergy Arkansas filed its final storm damage cost
determination, which reflects costs of approximately $195 million. The
filing asks for recovery of approximately $170 million through the rider
over approximately a six and one-half year period. The remainder of the
costs is primarily capital expenditures that will be included in rate
base in the general rate proceeding that is currently scheduled to be
filed in January 2002. No assurance can be give as to the timing or
outcome of these proceedings before the APSC.
Filings with the PUCT and Texas Cities
Recovery of River Bend Costs (Entergy Corporation and Entergy Gulf
States)
In March 1998, the PUCT disallowed recovery of $1.4 billion of
company-wide abeyed River Bend plant costs, which have been held in
abeyance since 1988. Entergy Gulf States appealed the PUCT's decision on
this matter to the Travis County District Court in Texas. Subsequent to
the June 1999 settlement agreement discussed in Note 2 to the financial
statements in the Form 10-K, Entergy Gulf States removed the reserve for
River Bend plant costs held in abeyance and reduced the net book value of
the plant asset. The June 1999 settlement agreement limits potential
recovery of the remaining plant asset, less depreciation, to $115 million
as of January 1, 2002. In the unbundled cost of service settlement
discussed above, and consistent with the June 1999 settlement, Entergy
Gulf States agrees not to prosecute its appeal until January 1, 2002.
Entergy Gulf States also agrees that it will not seek recovery of the
abeyed plant costs through any additional charge to Texas ratepayers. The
financial statement impact of the settlement agreement on the abeyed plant
costs will ultimately depend on several factors, including the possible
discontinuance of SFAS 71 accounting treatment to the Texas generation
business, the determination of the market value of generation assets, and
any future legislation in Texas addressing the pass-through or sharing of
any stranded benefits with Texas ratepayers. No assurance can be given
that additional reserves or write-offs will not be required in the future.
PUCT Fuel Cost Review (Entergy Corporation and Entergy Gulf States)
As determined in the June 1999 settlement agreement discussed in Note
2 to the financial statements in the Form 10-K, Entergy Gulf States
adopted a methodology for calculating its fixed fuel factor based on the
market price of natural gas. This calculation and any necessary
adjustments occur semi-annually. The settlement that delayed
implementation of retail open access in Texas for Entergy Gulf States
provides that Entergy Gulf States will continue the use of this
methodology until retail open access begins. The amounts collected under
Entergy Gulf States' fixed fuel factor through the date retail open access
commences are subject to fuel reconciliation proceedings before the PUCT.
In January 2001, Entergy Gulf States filed a fuel reconciliation case
covering the period from March 1, 1999 to August 31, 2000. Entergy Gulf
States is reconciling approximately $583 million of fuel and purchased
power costs. As part of this filing, Entergy Gulf States requested a
surcharge to collect $28 million, plus interest, of under-recovered fuel
and purchased power costs. A hearing on the merits concluded in August
2001 and issuance of a final order is pending. No assurance can be given
as to the outcome of this proceeding.
In November 2001, Entergy Gulf States filed an application with the
PUCT requesting an interim surcharge to collect $71 million, plus
interest, of under-recovered fuel and purchased power expenses incurred
from September 2000 through September 2001. Entergy Gulf States made the
application pursuant to one of the terms of the settlement agreement that
delayed implementation of retail open access in Texas for Entergy Gulf
States. Entergy Gulf States requests that the surcharge begin January 1,
2002 and end September 30, 2002. No assurance can be given as to the
outcome of this request.
Filings with the LPSC
Annual Earnings Reviews (Entergy Corporation and Entergy Gulf States)
In June 2001, the LPSC approved a settlement between Entergy Gulf
States and the LPSC staff to refund $25.9 million, including interest,
resolving issues in Entergy Gulf States' third, sixth, and seventh post-
merger earnings reviews filed with the LPSC in May 1996, 1999, and 2000,
respectively. The refund was made over a three-month period beginning
July 2001. The settlement resolved the prospective return on common
equity issue on remand from the Louisiana Supreme Court in the third
earnings review. Refund issues from the sixth and seventh earnings
reviews were also resolved; however, certain prospective issues remain in
dispute. The LPSC approved an 11.1% return on common equity through June
2003, which Entergy Gulf States was allowed to include in its eighth post-
merger earnings analysis discussed below.
In May 2001, Entergy Gulf States filed its eighth required post-
merger earnings analysis with the LPSC. This filing will be subject to
review by the LPSC, which may result in a change in rates. A procedural
schedule has been established by the LPSC and a hearing is scheduled for
April 2002.
Formula Rate Plan Filings (Entergy Corporation and Entergy Louisiana)
In May 2000, Entergy Louisiana submitted its fifth annual performance-
based formula rate plan filing. The filing used a 1999 test year. As a
result of this filing, Entergy Louisiana implemented a $24.8 million base
rate reduction in August 2000. In September 2001, the LPSC approved a
settlement in which Entergy Louisiana agreed to increase to $28.2 million
the total base rate reduction, effective August 2000. The settlement
resolves all issues in the proceeding except for Entergy Louisiana's claim
for an increase in its allowed return on common equity from 10.5% to
11.6%. A procedural schedule to address the return on common equity issue
has been established and a hearing is scheduled for February 2002.
In April 2001, Entergy Louisiana submitted its sixth annual
performance-based formula rate plan filing, which used a 2000 test year.
The filing indicated that an immaterial base rate reduction might be
appropriate. This filing will be subject to review by the LPSC. A
procedural schedule has been established and a hearing is scheduled for
March 2002.
Fuel Adjustment Clause Litigation (Entergy Corporation and Entergy
Louisiana)
In May 1998, a group of ratepayers filed a complaint against Entergy
Corporation, Entergy Power, and Entergy Louisiana in state court in
Orleans Parish purportedly on behalf of all Entergy Louisiana ratepayers.
The plaintiffs seek treble damages for alleged injuries arising from
alleged violations by the defendants of Louisiana's antitrust laws in
connection with the costs included in fuel filings with the LPSC and
passed through to ratepayers. Plaintiffs also requested that the LPSC
initiate a review of Entergy Louisiana's monthly fuel adjustment charge
filings and force restitution to ratepayers of all costs that the
plaintiffs allege were improperly included in those fuel adjustment
filings. A few parties intervened in the LPSC proceeding. In direct
testimony, plaintiffs purport to quantify many of their claims for the
period 1989 through 1998 in an amount totaling $544 million, plus
interest.
Entergy Louisiana agreed to settle both of these proceedings. The
LPSC approved the settlement agreement following a fairness hearing before
an ALJ in November 2000. The state court certified the plaintiff class
and approved the settlement after a fairness hearing in April 2001. Under
the terms of the settlement agreement, Entergy Louisiana agreed to refund
to customers approximately $72 million to resolve all claims arising out
of or relating to Entergy Louisiana's fuel adjustment clause filings from
January 1, 1975 through December 31, 1999, except with respect to
purchased power and associated costs included in the fuel adjustment
clause filings for the period May 1 through September 30, 1999. Entergy
Louisiana previously recorded reserves for the refund, which Entergy
Louisiana made through the fuel adjustment clause over a three-month
period beginning in July 2001.
Also under the terms of the settlement, Entergy Louisiana consents to
future fuel cost recovery under a long-term gas contract based on a
formula that would likely result in an under-recovery of actual costs for
the remainder of the contract's term, which runs through 2013. The future
under-recovery cannot be precisely estimated at this time because it will
depend upon factors that are not certain, such as the price of gas and the
amount of gas purchased under the long-term contract. In recent years,
Entergy Louisiana has made purchases under that contract totaling from $91
million to $121 million annually. Had the proposed settlement terms been
applicable to such purchases, the under-recoveries would have ranged from
$4 million to $9 million per year.
Filings with the MPSC (Entergy Corporation and Entergy Mississippi)
In March 2001, Entergy Mississippi submitted its annual performance-
based formula rate plan filing for the 2000 test year. The submittal
indicated that a $6.7 million rate increase was appropriate under the
formula rate plan. In April 2001, the MPSC staff and Entergy Mississippi
entered into a stipulation that provides for an increase of $5.6 million,
which was approved by the MPSC and was effective May 2001.
Filings with the Council (Entergy Corporation and Entergy New Orleans)
Rate Proceedings
In June 2001, Entergy New Orleans filed with the Council for changes
in gas and electric rates based on a test year ending December 31, 2000.
The filing indicated that an increase of $12.7 million in gas rates and an
increase of $12.5 million in electric rates might be appropriate.
Proceedings on Entergy New Orleans' filing have been deferred until June
2002. Entergy New Orleans' rate decrease that would have occurred in
October 2001 upon completion of its Grand Gulf 1 phase-in plan has also
been deferred. As a result of the deferral of the proceedings, Entergy
New Orleans' rates will remain at their current level at this time.
Fuel Adjustment Clause Litigation
In April 1999, a group of ratepayers filed a complaint against
Entergy New Orleans, Entergy Corporation, Entergy Services, and Entergy
Power in state court in Orleans Parish purportedly on behalf of all
Entergy New Orleans ratepayers. The plaintiffs seek treble damages for
alleged injuries arising from the defendants' alleged violations of
Louisiana's antitrust laws in connection with certain costs passed on to
ratepayers in Entergy New Orleans' fuel adjustment filings with the
Council. In particular, plaintiffs allege that Entergy New Orleans
improperly included certain costs in the calculation of fuel charges and
that Entergy New Orleans imprudently purchased high-cost fuel from other
Entergy affiliates. Plaintiffs allege that Entergy New Orleans and the
other defendant Entergy companies conspired to make these purchases to the
detriment of Entergy New Orleans' ratepayers and to the benefit of
Entergy's shareholders, in violation of Louisiana's antitrust laws.
Plaintiffs also seek to recover interest and attorneys' fees. Exceptions
to the plaintiffs' allegations were filed by Entergy, asserting, among
other things, that jurisdiction over these issues rests with the Council
and FERC. If necessary, at the appropriate time, Entergy will also raise
its defenses to the antitrust claims. At present, the suit in state court
is stayed by stipulation of the parties.
Plaintiffs also filed this complaint with the Council in order to
initiate a review by the Council of the plaintiffs' allegations and to
force restitution to ratepayers of all costs they allege were improperly
and imprudently included in the fuel adjustment filings. Discovery has
begun in the proceedings before the Council. Testimony was filed on
behalf of the plaintiffs in this proceeding in April 2000 and has been
supplemented. The testimony, as supplemented, asserts, among other
things, that Entergy New Orleans and other defendants have engaged in fuel
procurement and power purchasing practices and included costs in Entergy
New Orleans' fuel adjustment that could have resulted in New Orleans
customers being overcharged by more than $100 million over a period of
years. In June 2001, the Council's Advisors filed testimony on these
issues in which they allege that Entergy New Orleans ratepayers may have
been overcharged by more than $32 million, the vast majority of which is
reflected in the plaintiffs' claim. However, it is not clear precisely
what periods and damages are being alleged in the proceeding. Entergy
intends to defend this matter vigorously, both in court and before the
Council. Hearings are scheduled to begin in February 2002. The ultimate
outcome of the lawsuit and the Council proceeding cannot be predicted at
this time.
Natural Gas Purchases
In a resolution adopted August 2, 2001, the Council ordered Entergy
New Orleans to account for $30.1 million of certain natural gas costs
charged to its gas distribution customers from July 1997 through May 2001.
The resolution suggests that refunds may be due to the gas distribution
customers if Entergy New Orleans cannot account satisfactorily for these
costs. Entergy New Orleans filed a response to the Council in September
2001. Entergy New Orleans has documented a full reconciliation for the
natural gas costs during that period. The ultimate outcome of the
proceeding cannot be predicted at this time.
Proposed System Energy Rate Increase (Entergy Corporation, Entergy
Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and
System Energy)
As discussed in Note 2 to the financial statements in the Form 10-K,
System Energy applied to FERC in May 1995 for a $65.5 million rate
increase. The request sought changes to System Energy's rate schedule,
including increases in the revenue requirement associated with
decommissioning costs, the depreciation rate, and the rate of return on
common equity. System Energy implemented the rate increase in December
1995.
After a hearing, FERC issued an order in the proceeding in July 2000.
FERC affirmed the ALJ's adoption of a 10.8% return on equity, but modified
the return to reflect changes in capital market conditions since the ALJ's
decision. FERC adjusted the rate of return to 10.58% for the period
December 1995 to the date of FERC's decision, and prospectively adjusted
the rate of return to 10.94% from the date of FERC's decision. FERC's
decision also changed other aspects of System Energy's proposed rate
schedule, including the depreciation rate and decommissioning costs and
their methodology.
In July 2001, FERC denied requests for rehearing and the July 2000
order became final. FERC also ordered System Energy to file a compliance
tariff to the July 2000 order and to make refunds in compliance with the
order within 30 days after acceptance of the tariff. FERC has not acted
on the compliance tariff filing, which System Energy made on August 29,
2001.
In accord with regulatory accounting principles, during the pendency
of the case System Energy recorded reserves for potential refunds against
its revenues. Upon the order becoming final, Entergy Arkansas, Entergy
Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy
recorded entries to spread the impacts of FERC's order to the various
revenue, expense, asset, and liability accounts affected, as if the order
had been in place since commencement of the case in 1995. System Energy
also recorded an additional reserve amount against its revenue, to adjust
its estimate of the impact of the order, and recorded additional interest
expense on that reserve. System Energy also recorded reductions in its
depreciation and its decommissioning expenses to reflect the lower levels
in FERC's order, and reduced tax expense affected by the order.
In August 2001, Entergy Arkansas filed an application with the APSC
for approval of a plan to refund to ratepayers approximately $62.5 million
in early 2002 as a result of the final FERC order in System Energy's rate
increase proceeding. In October 2001, the APSC approved the issuance of
refund checks to Entergy Arkansas' ratepayers.
Entergy Mississippi's allocation of the proposed System Energy
wholesale rate increase is $21.6 million annually. In July 1995, Entergy
Mississippi filed a schedule with the MPSC that deferred the retail
recovery of the System Energy rate increase. The deferral plan, which was
approved by the MPSC, began in December 1995, the effective date of the
System Energy rate increase, and was effective until the issuance of the
final order by FERC. Under this plan, the deferral period was anticipated
to have ended by September 1998, and the deferred amount would have been
amortized over 48 months beginning in October 1998. Entergy Mississippi
filed a revised deferral plan with the MPSC in August 1998 that provided
for recovery, effective with October 1998 billings, of $11.8 million of
the System Energy rate increase that was approved by the FERC ALJ's
initial decision in July 1996. The $11.8 million was being amortized over
the original 48-month period, which began in October 1998. In August
2000, as a result of the July 2000 FERC Order and Entergy's request for
rehearing, Entergy Mississippi filed a second revised deferral plan with
the MPSC that provides for a one year suspension of the recovery of the
ALJ amount deferred prior to October 1998. The amount of System Energy's
proposed increase in excess of the $11.8 million was also deferred until
the issuance of a final order by FERC, or October 2002, whichever occurred
first. As a result of the final resolution of the FERC order and in
accordance with Entergy Mississippi's second revised deferral plan,
refunds to Entergy Mississippi from System Energy, including interest,
will be credited against deferral balances and any refund amounts in
excess of the deferral balances will be included as a credit to the
amounts billed in October 2001 through September 2002 to Entergy
Mississippi's customers under its Grand Gulf Riders.
Grand Gulf Accelerated Recovery Tariff (Entergy Arkansas)
In April 1998, FERC approved the GGART that Entergy Arkansas filed as
part of the settlement agreement that the APSC approved in December 1997.
The GGART was designed to allow Entergy Arkansas to pay down a portion of
its Grand Gulf purchased power obligation in advance of the implementation
of retail access in Arkansas. The GGART provides for the acceleration of
$165.3 million of its obligation over the period January 1, 1999 through
June 30, 2004. In April 2001, FERC approved Entergy Arkansas' filing that
requested cessation of the GGART effective July 1, 2001. Entergy Arkansas
made the filing pursuant to the terms of a December 2000 settlement
agreement with the APSC, which is discussed in Note 2 to the financial
statements in the Form 10-K.
NOTE 3. COMMON STOCK (Entergy Corporation)
During the nine months ended September 30, 2001, Entergy Corporation
repurchased 989,100 shares of common stock in the open market for an
aggregate purchase price of approximately $36.9 million.
During the nine months ended September 30, 2001, Entergy Corporation
issued 2,317,797 shares of its previously repurchased common stock to
satisfy stock options exercised and employee stock purchases. In
addition, Entergy Corporation received proceeds of approximately $2.1
million from the issuance of 79,473 shares of common stock to satisfy
stock options exercised.
NOTE 4. LONG-TERM DEBT
(Entergy Corporation)
On August 24, 2001, Entergy Corporation paid off the outstanding
Saltend Project credit facilities of approximately $550 million using
proceeds from the sale of the plant.
(Entergy Arkansas)
On July 17, 2001, Entergy Arkansas issued $100 million of 6.125%
Series First Mortgage Bonds due July 1, 2005. The proceeds are being used
for general corporate purposes, including the retirement of short-term
indebtedness associated with ice storm expenses.
(Entergy Gulf States)
On August 1, 2001, Entergy Gulf States retired, at maturity, $122.8
million of 6.41% Series First Mortgage Bonds with internally generated
funds, primarily from the Entergy inter-company money pool funding
arrangement.
On August 22, 2001, Entergy Gulf States issued $300 million of
Floating Rate Series First Mortgage Bonds due September 1, 2004, with an
initial interest rate of 4.829% per annum. The proceeds were used to
reduce the short-term debt that was incurred to repay, at maturity, $122.8
million of 6.41% Series First Mortgage Bonds due August 1, 2001 and for
general corporate purposes. The proceeds will also be used to repay, at
maturity, $150 million of 8.21% Series First Mortgage Bonds due January 1,
2002.
(Entergy Louisiana)
On April 1, 2001, Entergy Louisiana retired, at maturity, $18.7
million of 7.875% Series First Mortgage Bonds with internally generated
funds.
(Entergy Mississippi)
On January 31, 2001, Entergy Mississippi issued $70 million of 6.25%
Series First Mortgage Bonds due February 1, 2003. The proceeds are being
used for general corporate purposes, including the retirement of short-
term indebtedness incurred from money pool borrowings for capital
expenditures and working capital needs.
(Entergy New Orleans)
On February 23, 2001, Entergy New Orleans issued $30 million of 6.65%
Series First Mortgage Bonds due March 1, 2004. The proceeds are being used
for general corporate purposes, including the retirement of short-term
indebtedness incurred from money pool borrowings for capital expenditures
and working capital needs.
(System Energy)
On August 1, 2001, System Energy retired, at maturity, $135 million
of 7.71% Series First Mortgage Bonds with internally generated funds.
NOTE 5. RETAINED EARNINGS (Entergy Corporation)
On October 26, 2001, Entergy Corporation's Board of Directors
declared a common stock dividend of $0.33 per share, payable on December
1, 2001, to holders of record on November 13, 2001.
NOTE 6. BUSINESS SEGMENT INFORMATION (Entergy Corporation)
Entergy's reportable segments as of September 30, 2001, are domestic
utility and System Energy, energy commodity services, and domestic non-
utility nuclear. During the third quarter of 2001, Entergy began
integration of Entergy-Koch and Entergy Wholesale Operations into the
energy commodity services segment. Prior to the third quarter of 2001,
Entergy-Koch and Entergy Wholesale Operations were reported as separate
segments.
Prior to the first quarter of 2001, Entergy reported its power
marketing and trading segment that engaged in the marketing of wholesale
electricity, gas, other generating fuels, electric capacity, and financial
instruments. On January 31, 2001, Entergy contributed substantially all
of its power marketing and trading business to Entergy-Koch, which is now
a part of the energy commodity services segment. Results from Entergy-
Koch are reported as equity in earnings of unconsolidated equity
affiliates in the financial statements. See Note 9 to the financial
statements for further discussion of the investment in Entergy-Koch, L.P.
Entergy Wholesale Operations, which includes Entergy's global power
development business and is now part of the energy commodity services
segment, and domestic non-utility nuclear were reported in "all other"
prior to 2001. "All Other" now includes the parent company, Entergy
Corporation, and other business activity, which is principally gains or
losses on the sales of businesses and the earnings on the proceeds of
those sales.
Entergy's segment financial information for the three months ended
September 30, 2001 and 2000 is as follows (in thousands):
Domestic Energy Domestic Non-All Other* Eliminations Consolidated
Utility Commodity Utility
and System Services* Nuclear *
Energy
2001
Operating Revenues $2,005,043 $361,760 $203,783 $5,970 ($820) $2,575,736
Equity in Earnings
of Unconsolidated
Equity Affiliates - 58,414 - - - 58,414
Income Taxes (Benefit) 125,218 44,138 23,399 (7,455) - 185,300
Net Income (Loss) 228,523 67,241 34,636 (12,946) - 317,454
2000
Operating Revenues $2,412,482 $971,428 $56,962 $8,240 ($17,557) $3,431,555
Income Taxes (Benefit) 199,142 5,404 4,799 (1,418) - 207,927
Net Income 290,694 6,827 6,547 2,621 - 306,689
Entergy's segment financial information for the nine months ended
September 30, 2001 and 2000 is as follows (in thousands):
Domestic Energy Domestic Non-All Other* Eliminations Consolidated
Utility Commodity Utility
and System Services* Nuclear *
Energy
2001
Operating Revenues $6,011,105 $1,155,738 $533,199 $26,450 ($3,054) $7,723,438
Equity in Earnings
of Unconsolidated
Equity Affiliates - 153,957 - - - 153,957
Income Taxes (Benefit) 325,951 78,706 65,642 (10,726) - 459,573
Net Income (Loss) 524,116 115,765 98,966 (14,940) - 723,907
Total Assets 20,597,897 2,210,727 3,367,953 878,371 (873,314) 26,181,634
2000
Operating Revenues $5,511,403 $1,709,003 $179,911 $22,515 ($41,997) $7,380,835
Income Taxes 390,640 22,549 21,843 5,584 - 440,616
Net Income 564,978 48,699 30,078 17,117 - 660,872
Total Assets 20,560,181 2,280,131 645,698 1,070,935 (529,842) 24,027,103
Businesses marked with * are sometimes referred to as the "competitive
businesses," with the exception of the parent company, Entergy
Corporation. Eliminations are primarily inter-segment activity.
NOTE 7. ENTERGY-FPL GROUP MERGER (Entergy Corporation)
On July 30, 2000, Entergy Corporation and FPL Group, Inc. entered
into a Merger Agreement providing for a business combination that would
have resulted in the creation of a new company. On April 1, 2001, Entergy
Corporation and FPL Group, Inc. terminated the Merger Agreement by mutual
decision. Both companies agreed that no termination fee is payable under
the terms of the Merger Agreement, unless within nine months of the
termination one party agrees to a substantially similar transaction with
another party. Each company will bear its own merger-related expenses.
Entergy has withdrawn its merger-related filings submitted to the FERC,
the SEC, and state and local regulatory agencies.
NOTE 8. DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES (Entergy
Corporation, Entergy Arkansas, Entergy Gulf States, Entergy Louisiana,
Entergy Mississippi, Entergy New Orleans, and System Energy)
In June 1998, the FASB issued SFAS 133, "Accounting for Derivative
Instruments and Hedging Activities," which was implemented effective
January 1, 2001. This statement requires that all derivatives be
recognized in the balance sheet, either as assets or liabilities, at fair
value. The changes in the fair value of derivatives are recorded each
period in current earnings or other comprehensive income, depending on
whether a derivative is designated as part of a hedge transaction and, if
it is, the type of hedge transaction. For fair-value hedge transactions in
which Entergy is hedging changes in an asset's, liability's, or firm
commitment's fair value, changes in the fair value of the derivative
instrument will generally be offset in the income statement by changes in
the hedged item's fair value. For cash-flow hedge transactions in which
Entergy is hedging the variability of cash flows related to a variable-
rate asset, liability, or a forecasted transaction, changes in the fair
value of the derivative instrument will be reported in other comprehensive
income. The gains and losses on the derivative instrument that are
reported in other comprehensive income will be reclassified as earnings in
the periods in which earnings are impacted by the variability of the cash
flows of the hedged item. The ineffective portion of all hedges will be
recognized in current-period earnings.
Entergy utilizes derivative financial instruments primarily for the
following purposes:
o to ensure adequate power supplies and to mitigate certain risks in
the domestic utility business; and
o to hedge cash flows for certain risks in its competitive businesses,
including certain interest rate, currency, and commodity price risks.
The implementation of SFAS 133 did not materially impact the power
marketing and trading business, as its derivative portfolio was already
marked-to-market under the provisions of EITF 98-10, "Measuring the Value
of Energy-Related Contracts". Effective January 1, 2001, Entergy recorded
a net-of-tax cumulative-effect-type adjustment of approximately $18.0
million reducing accumulated other comprehensive income to recognize at
fair value all derivative instruments that are designated as cash-flow
hedging instruments, primarily interest rate swaps and foreign currency
forward contracts related to Entergy's competitive businesses.
FASB recently adopted certain interpretations of SFAS 133, and is
considering other interpretations of that standard, that will affect
Entergy's future financial statements. Entergy expects to implement these
interpretations by no later than the second quarter of 2002. Entergy has
not completed its assessment of the impact of these interpretations.
NOTE 9. ACQUISITIONS, DISPOSITIONS, AND EQUITY METHOD INVESTMENTS
(Entergy Corporation)
Acquisition of Indian Point 2
In September 2001, Entergy's domestic non-utility nuclear business
acquired the 951 MW Indian Point 2 nuclear power plant located in
Westchester County, New York from Consolidated Edison. Entergy paid
approximately $600 million in cash at the closing of the purchase and
received the plant, nuclear fuel, materials and supplies, a purchase power
agreement (PPA), and assumed certain liabilities. On the second
anniversary of the Indian Point 2 acquisition, Entergy's nuclear business
will also begin to pay NYPA $10 million per year for up to 10 years in
accordance with the Indian Point 3 purchase agreement. Under the PPA,
Consolidated Edison will purchase 100% of Indian Point 2's output for an
average price of $39/MWh through 2004. Consolidated Edison transferred a
$430 million decommissioning trust fund, along with the liability to
decommission Indian Point 2 and Indian Point 1, to Entergy. Entergy
acquired Indian Point 1 in the transaction, a plant that has been shut
down and in safe storage since the 1970s.
The acquisition was accounted for using the purchase method. The
results of operations of Indian Point 2 subsequent to the purchase date
have been included in Entergy's consolidated results of operations. The
Indian Point 2 purchase price has been preliminarily allocated to the
assets acquired and liabilities assumed based on their estimated fair
values on the purchase date. The allocation was based on preliminary
information and ultimate amounts are likely to change.
Asset Disposition
In August 2001, Entergy's EWO business sold the Saltend plant to
Calpine Corporation for a cash payment of approximately $800 million.
Entergy's gain on the sale was approximately $69.9 million ($45.4 million
after tax). The results of operations of the Saltend plant are included
in Entergy's consolidated statements of income through the date of sale.
The gain arising from the sale is included in operating revenues in that
statement. EWO actively manages its assets as an investment portfolio, and
attempts to maximize flexibility to respond to different market
environments. Active management of the portfolio will continue to result
in: the sale of projects at various stages in their planning,
development, or operation; the abandonment of projects; or, the commercial
operation of projects by EWO. In the sales transaction, Entergy or its
subsidiaries made certain warranties to the purchasers. Entergy believes
that it has provided adequate reserves for these warranties as of
September 30, 2001.
Equity Method Investments
On January 31, 2001, subsidiaries of Entergy and Koch Industries,
Inc. formed Entergy-Koch, L.P., a limited partnership equally owned by
Entergy and Koch Industries, Inc. An eight-member board of directors,
equally appointed by Entergy and Koch Industries, Inc., governs Entergy-
Koch, L.P. As part of the joint venture agreement, Entergy contributed
substantially all of its power marketing and trading business in the
United States and the United Kingdom and made other contributions,
including equity and loans, totaling $414 million. Koch contributed to
the venture its 9,000-mile Koch Gateway Pipeline (which has been renamed
the Gulf South Pipeline), gas storage facilities, including the Bistineau
storage facility near Shreveport, Louisiana, and Koch Energy Trading,
which marketed and traded electricity, gas, weather derivatives, and other
energy-related commodities and services. Entergy's investment in Entergy-
Koch, L.P. is accounted for under the equity method of accounting.
Certain terms of the partnership arrangement allocate income from various
sources, and the taxes on that income, on a disproportionate basis. These
disproportionate allocations have been favorable to Entergy in the
aggregate in 2001.
Entergy also owns investments in the following companies that it
accounts for under the equity method of accounting: Generandes Peru S.A.,
in which it owns 34% of the voting power; Compania Electrica San Isidro
S.A., in which it owns 25% of the voting power; RS Cogen LLC, in which it
holds a 50% member interest; and EntergyShaw LLC, in which it holds a 50%
member interest. Following is a summary of combined financial information
reported by Entergy's equity method investees (in thousands):
September 30, 2001 Three Months Nine Months
Ended Ended
Income Statement Items
Operating revenues $2,909,807 $7,727,012
Operating income 92,925 232,988
Net income 67,483 183,251
Balance Sheet Items
Current assets $2,831,424
Noncurrent assets 2,961,457
Current liabilities 2,534,427
Noncurrent liabilities 1,345,572
Prior to the formation of Entergy-Koch in January 2001 and its results
during 2001, Entergy's equity method investees were immaterial to its
results of operations and financial position. Therefore, summarized
financial information for 2000 is not presented.
NOTE 10. NEW ACCOUNTING PRONOUNCEMENTS (Entergy Corporation, Entergy
Arkansas, Entergy Gulf States, Entergy Louisiana, Entergy Mississippi,
Entergy New Orleans, and System Energy)
In mid-2001, the FASB issued the following pronouncements:
o SFAS 141, "Business Combinations";
o SFAS 142, "Goodwill and Other Intangible Assets";
o SFAS 143, "Accounting for Asset Retirement Obligations"; and
o SFAS 144, "Accounting for the Impairment or Disposal of Long-lived
Assets".
SFAS 141, which Entergy will implement for all business combinations
initiated after June 30, 2001, eliminates the pooling-of-interests method
of accounting for business combinations and requires that all business
combinations be accounted for using the purchase accounting method. SFAS
141 also requires the recording of all acquired intangible assets that
either arise from contractual or legal rights, or that are separable from
the acquired entity. The implementation of SFAS 141 on July 1, 2001 had no
impact on Entergy's financial statements.
SFAS 142, which Entergy will implement effective January 1, 2002,
eliminates the amortization of goodwill arising from business
combinations. Instead, goodwill will be subject to a periodic impairment
test at the "reporting unit" level. SFAS 142 also eliminates the
arbitrary 40-year cap on useful lives of intangible assets, and
acknowledges that some intangible assets may have indefinite useful lives.
The implementation of SFAS 142 will require Entergy to cease the
amortization of the remaining acquisition adjustment recorded in
conjunction with its acquisition of Entergy Gulf States. Entergy will
also be required to perform an impairment test on the remaining
acquisition adjustment. Entergy has not completed its assessment of the
impact of the implementation of this standard.
SFAS 143, which is required to be implemented by January 1, 2003,
requires the recording of liabilities for all legal obligations associated
with the retirement of long-lived assets that result from the normal
operation of those assets. These liabilities are required to be recorded
at their fair values (which are likely to be the present values of the
estimated future cash flows) in the period in which they are incurred.
SFAS 143 requires the associated asset retirement costs to be capitalized
as part of the carrying amount of the long-lived asset. The asset
retirement obligation will be accreted each year through a charge to
expense. The amounts added to the carrying amounts of the assets will be
depreciated over the useful lives of the assets. Upon adoption, the net
effects of implementing this standard, to the extent that they are not
recorded as regulatory assets or liabilities, will be recognized as
cumulative effects of an accounting change in Entergy's income statement.
Entergy has not yet completed its assessment of the likely overall impact
of this standard on its financial statements.
SFAS 144, which Entergy will implement effective January 1, 2002,
promulgates standards for measuring and recording impairments of long-
lived assets. Additionally, this standard establishes requirements for
classifying an asset as held for sale, and changes existing accounting and
reporting standards for discontinued operations and exchanges of long-
lived assets. Entergy does not expect the implementation of this standard
to have a significant effect on Entergy's financial position or results of
operations.
__________________________________
In the opinion of the management of Entergy Corporation, Entergy
Arkansas, Entergy Gulf States, Entergy Louisiana, Entergy Mississippi,
Entergy New Orleans, and System Energy, the accompanying unaudited
condensed financial statements contain all adjustments (consisting
primarily of normal recurring accruals and reclassification of previously
reported amounts to conform to current classifications) necessary for a
fair statement of the results for the interim periods presented. However,
the business of the domestic utility companies and System Energy is
subject to seasonal fluctuations with the peak periods occurring during
the third quarter. The results for the interim periods presented should
not be used as a basis for estimating results of operations for a full
year.
ENTERGY CORPORATION AND SUBSIDIARIES
PART II. OTHER INFORMATION
Item 1. Legal Proceedings
See "PART I, Item 1, Other Regulation and Litigation" in the Form 10-
K for a discussion of legal proceedings affecting Entergy. Set forth
below are updates to the information contained in the Form 10-K.
Ratepayer Lawsuits (Entergy Corporation, Entergy Gulf States, Entergy
Louisiana, and Entergy New Orleans)
See "Ratepayer Lawsuits, Entergy Louisiana Fuel Clause Lawsuit" in
Item 1 of Part I of the Form 10-K for a discussion of the complaints filed
by ratepayers with the LPSC and in Louisiana state court in Orleans
Parish. See "Filings with the LPSC, Fuel Adjustment Clause Litigation"
and "Filings with the Council, Fuel Adjustment Clause Litigation" in Note
2 to the financial statements herein for developments that have occurred
since the filing of the Form 10-K.
See "Ratepayer Lawsuits, Vidalia Project Sub-Docket" in Item 1 of
Part I of the Form 10-K and in Item 1 of Part II of the 2001 first quarter
Form 10-Q for a discussion of the sub-docket established in the Entergy
Louisiana Fuel Clause Lawsuit at the LPSC.
Franchise Service Area Litigation (Entergy Gulf States)
See "Franchise Service Area Litigation" in Item 1 of Part I of the
Form 10-K for a discussion of the litigation with Beaumont Power & Light
(BP&L). In May 2000, the PUCT voted to remand the proceeding back to the
ALJ to allow BP&L to provide further evidence. A hearing on the merits of
the case has been scheduled for November 2001.
Hindusthan Development Corporation, Ltd. (Entergy Corporation)
See "Hindusthan Development Corporation, Ltd." in Item 1 of Part I of
the Form 10-K for a discussion of the arbitration proceeding in India
against Entergy Power Asia Ltd. (EPAL), a wholly-owned subsidiary of
Entergy Corporation. In the second quarter of 2001, EPAL and HDC settled
the arbitration for an immaterial amount, and the claim has been
dismissed.
Item 4. Submission of Matters to a Vote of Security Holders
(System Energy)
A consent in lieu of the annual meeting of common stockholders was
executed on July 31, 2001. The consent was signed on behalf of Entergy
Corporation, the holder of all issued and outstanding shares of common
stock. The common stockholder, by such consent, elected the following
individuals to serve as directors constituting the Board of Directors of
System Energy: Jerry W. Yelverton, Donald C. Hintz, and C. John Wilder.
Item 5. Other Information
Environmental Regulation (Entergy Gulf States)
The State of Louisiana is considering future emission control
strategies to address continued ozone non-attainment status of areas in
and around Baton Rouge, Louisiana. In August 2001 the LDEQ published a
notice of intent to issue a rule for control of NOx as part of the State
Implementation Plan (SIP) to bring this area into attainment with the
National Ambient Air Quality standards for ozone by May 2005. The notice
contains certain provisions that would lead to installation of new NOx
control equipment at Entergy Gulf States generating units. Preliminary
analyses indicate compliance costs may be as much as $47 million overall.
Most of the related expenditures would take place in 2003 and 2004. The
final rule is expected to be in place by December 2001. Cost estimates
will be refined as engineering studies progress before and after
promulgation of the final NOx rule. Entergy Gulf States will be required
to obtain revised operating permits from LDEQ and meet new, lower emission
limits for NOx. Entergy expects to file before October 2002 revised
permit applications containing its detailed compliance strategy. In late
August 2001, however, a federal magistrate issued a report recommending
that the EPA be ordered to make a determination regarding the ozone non-
attainment status and any reclassification of the area required as a
result of the determination. The recommendation might result in an
upgrade from the current status of "serious" to "severe" non-attainment
classification for the Baton Rouge area. If this occurs, LDEQ ozone SIP
rulemakings could be affected, especially in terms of scheduling. The
specific impact of the magistrate's recommendation on Entergy Gulf States
will remain unclear until the EPA responds to the magistrate's report.
Earnings Ratios (Entergy Arkansas, Entergy Gulf States, Entergy
Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)
The domestic utility companies and System Energy have calculated
ratios of earnings to fixed charges and ratios of earnings to combined
fixed charges and preferred dividends pursuant to Item 503 of Regulation
S-K of the SEC as follows:
Ratios of Earnings to Fixed Charges
Twelve Months Ended
December 31, September 30,
1996 1997 1998 1999 2000 2001
Entergy Arkansas 2.93 2.54 2.63 2.08 3.01 3.48
Entergy Gulf States 1.47 1.42 1.40 2.18 2.60 2.39
Entergy Louisiana 3.16 2.74 3.18 3.48 3.33 3.13
Entergy Mississippi 3.40 2.98 3.12 2.44 2.33 2.30
Entergy New Orleans 3.51 2.70 2.65 3.00 2.66 (b)
System Energy 2.21 2.31 2.52 1.90 2.41 2.02
Ratios of Earnings to Combined Fixed Charges
and Preferred Dividends
Twelve Months Ended
December 31, September 30,
1996 1997 1998 1999 2000 2001
Entergy Arkansas 2.44 2.24 2.28 1.80 2.70 3.13
Entergy Gulf States (a) 1.19 1.23 1.20 1.86 2.39 2.29
Entergy Louisiana 2.64 2.36 2.75 3.09 2.93 2.82
Entergy Mississippi 2.95 2.69 2.80 2.18 2.09 2.10
Entergy New Orleans 3.22 2.44 2.41 2.74 2.43 (b)
(a) "Preferred Dividends" in the case of Entergy Gulf States also
include dividends on preference stock.
(b) Earnings for the twelve months ended September 30, 2001, for
Entergy New Orleans were not adequate to cover fixed charges
and combined fixed charges and preferred dividends by $11.4
million and $13.1 million, respectively.
Item 6. Exhibits and Reports on Form 8-K
(a) Exhibits*
4(a) - Fifty-sixth Supplemental Indenture, dated as of July 1,
2001, to Entergy Arkansas' Mortgage and Deed of Trust,
dated as of October 1, 1944.
** 4(b) - Assumption Agreement, dated July 12, 2001, among First
Union National Bank, as Additional Lender, Entergy and
Citibank N.A., as Agent (filed as Exhibit 5(a) to Rule 24
Certificate dated November 6, 2001 in File No. 70-9749).
** 4(b) - Sixtieth Supplemental Indenture, dated as of August 1,
2001, to Entergy Gulf States' Mortgage and Deed of Trust,
dated as of September 1, 1926 (filed as Exhibit A-2(a) to
Rule 24 Certificate dated September 10, 2001 in File No.
70-9751).
99(a) - Entergy Arkansas' Computation of Ratios of Earnings to
Fixed Charges and of Earnings to Combined Fixed Charges
and Preferred Dividends, as defined.
99(b) - Entergy Gulf States' Computation of Ratios of Earnings to
Fixed Charges and of Earnings to Combined Fixed Charges
and Preferred Dividends, as defined.
99(c) - Entergy Louisiana's Computation of Ratios of Earnings to
Fixed Charges and of Earnings to Combined Fixed Charges
and Preferred Dividends, as defined.
99(d) - Entergy Mississippi's Computation of Ratios of Earnings
to Fixed Charges and of Earnings to Combined Fixed
Charges and Preferred Dividends, as defined.
99(e) - Entergy New Orleans' Computation of Ratios of Earnings to
Fixed Charges and of Earnings to Combined Fixed Charges
and Preferred Dividends, as defined.
99(f) - System Energy's Computation of Ratios of Earnings to
Fixed Charges, as defined.
___________________________
Pursuant to Item 601(b)(4)(iii) of Regulation S-K, Entergy Corporation
agrees to furnish to the Commission upon request any instrument with
respect to long-term debt that is not registered or listed herein as an
Exhibit because the total amount of securities authorized under such
agreement does not exceed ten percent of Entergy Corporation and its
subsidiaries on a consolidated basis.
* Reference is made to a duplicate list of exhibits being
filed as a part of this report on Form 10-Q for the quarter
ended September 30, 2001, which list, prepared in
accordance with Item 102 of Regulation S-T of the SEC,
immediately precedes the exhibits being filed with this
report on Form 10-Q for the quarter ended September 30,
2001.
** Incorporated herein by reference as indicated.
(b) Reports on Form 8-K
Entergy Corporation
A Current Report on Form 8-K, dated July 3, 2001, was
filed with the SEC on July 5, 2001, reporting
information under Item 7. "Financial Statements, Pro
Forma Financial Statements and Exhibits" and Item 9.
"Regulation FD Disclosure".
Entergy Corporation
A Current Report on Form 8-K, dated July 5, 2001, was
filed with the SEC on July 5, 2001, reporting
information under Item 5. "Other Events" and Item 7.
"Financial Statements, Pro Forma Financial Statements
and Exhibits".
Entergy Corporation
A Current Report on Form 8-K, dated July 5, 2001, was
filed with the SEC on July 5, 2001, reporting
information under Item 7. "Financial Statements, Pro
Forma Financial Statements and Exhibits" and Item 9.
"Regulation FD Disclosure".
Entergy Arkansas, Entergy Gulf States, Entergy Louisiana,
Entergy Mississippi, Entergy New Orleans, and System Energy
A Current Report on Form 8-K, dated July 6, 2001, was
filed with the SEC on July 13, 2001, reporting
information under Item 5. "Other Events".
Entergy Corporation
A Current Report on Form 8-K, dated July 31, 2001,
was filed with the SEC on July 31, 2001, reporting
information under Item 7. "Financial Statements, Pro
Forma Financial Statements and Exhibits" and Item 9.
"Regulation FD Disclosure".
Entergy Corporation, Entergy Arkansas, Entergy Gulf States,
Entergy Louisiana, Entergy Mississippi, Entergy New
Orleans, and System Energy
A Current Report on Form 8-K, dated August 13, 2001,
was filed with the SEC on August 13, 2001, reporting
information under Item 4. "Changes in Registrant's
Certifying Accountant" and Item 7. "Financial
Statements, Pro Forma Financial Statements and
Exhibits".
Entergy Corporation
A Current Report on Form 8-K, dated August 15, 2001,
was filed with the SEC on August 15, 2001, reporting
information under Item 5. "Other Events", Item 7.
"Financial Statements, Pro Forma Financial Statements
and Exhibits" and Item 9. "Regulation FD Disclosure".
Entergy Corporation
A Current Report on Form 8-K, dated September 26,
2001, was filed with the SEC on September 26, 2001,
reporting information under Item 7. "Financial
Statements, Pro Forma Financial Statements and
Exhibits" and Item 9. "Regulation FD Disclosure".
Entergy Gulf States
A Current Report on Form 8-K, dated October 5, 2001,
was filed with the SEC on October 15, 2001, reporting
information under Item 5. "Other Events" and Item 7.
"Financial Statements, Pro Forma Financial Statements
and Exhibits".
Entergy Corporation
A Current Report on Form 8-K, dated October 22, 2001,
was filed with the SEC on October 22, 2001, reporting
information under Item 7. "Financial Statements, Pro
Forma Financial Statements and Exhibits" and Item 9.
"Regulation FD Disclosure".
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934,
each registrant has duly caused this report to be signed on its behalf by
the undersigned thereunto duly authorized. The signature for each
undersigned company shall be deemed to relate only to matters having
reference to such company or its subsidiaries.
ENTERGY CORPORATION
ENTERGY ARKANSAS, INC.
ENTERGY GULF STATES, INC.
ENTERGY LOUISIANA, INC.
ENTERGY MISSISSIPPI, INC.
ENTERGY NEW ORLEANS, INC.
SYSTEM ENERGY RESOURCES, INC.
/s/ Nathan E. Langston
Nathan E. Langston
Senior Vice President and Chief Accounting Officer
(For each Registrant and for each as
Principal Accounting Officer)
Date: November 9, 2001