SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-K/A
(MARK ONE)
[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
FOR THE FISCAL YEAR ENDED DECEMBER 31, 2002
OR
[ ] 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; AND TELEPHONE NUMBER IDENTIFICATION NO.
----------- ----------------------------- ------------------
AMENDMENT NO. 2
333-21011 FIRSTENERGY CORP. 34-1843785
(AN OHIO CORPORATION)
76 SOUTH MAIN STREET
AKRON, OH 44308
TELEPHONE (800)736-3402
AMENDMENT NO. 1
1-2578 OHIO EDISON COMPANY 34-0437786
(AN OHIO CORPORATION) C/O
FIRSTENERGY CORP.
76 SOUTH MAIN STREET
AKRON, OH 44308
TELEPHONE (800)736-3402
1-2323 THE CLEVELAND ELECTRIC ILLUMINATING COMPANY 34-0150020
(AN OHIO CORPORATION)
C/O FIRSTENERGY CORP.
76 SOUTH MAIN STREET
AKRON, OH 44308
TELEPHONE (800)736-3402
1-3583 THE TOLEDO EDISON COMPANY 34-4375005
(AN OHIO CORPORATION)
C/O FIRSTENERGY CORP.
76 SOUTH MAIN STREET
AKRON, OH 44308
TELEPHONE (800)736-3402
SECURITIES REGISTERED PURSUANT TO SECTION 12(B) OF THE ACT:
NAME OF EACH EXCHANGE
REGISTRANT TITLE OF EACH CLASS ON WHICH REGISTERED
---------- ------------------- -------------------
FirstEnergy Corp. Common Stock, $0.10 par value New York Stock Exchange
Ohio Edison Company Cumulative Preferred Stock, $100 par value:
3.90% Series All series registered on New
4.40% Series York Stock Exchange and
4.44% Series Chicago Stock Exchange
4.56% Series
The Cleveland Electric Cumulative Serial Preferred Stock, without
Illuminating Company par value:
$7.40 Series A Both series registered on New
Adjustable Rate, Series L York Stock Exchange
The Toledo Edison Cumulative Preferred Stock, par value
Company $100 per share:
4.25% Series American Stock Exchange
Cumulative Preferred Stock, par value $25 per
share:
$2.365 Series All series registered on
Adjustable Rate, Series A New York Stock Exchange
Adjustable Rate, Series B
First Mortgage Bonds:
8% Series due 2003 New York Stock Exchange
SECURITIES REGISTERED PURSUANT TO SECTION 12(G) OF THE ACT:
None
Indicate by check mark whether the registrant (1) has 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
registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days: Yes (X) No ( )
Indicate by check mark if disclosure of delinquent filers pursuant to
Item 405 of Regulation S-K is not contained herein, and will not be contained,
to the best of registrant's knowledge, in definitive proxy or information
statements incorporated by reference in Part III of this Form 10-K or any
amendment to this Form 10-K. (X)
Indicate by check mark whether each registrant is an accelerated filer
(as defined in Rule 12b-2 of the Act): Yes (X) No ( ) - --
State the aggregate market value of the common stock held by
non-affiliates of the registrant: FirstEnergy Corp., $9,920,663,231 as of June
28, 2002; and for all other registrants, none.
Indicate the number of shares outstanding of each of the registrant's
classes of common stock, as of the latest practicable date:
OUTSTANDING
CLASS AS OF MARCH 24, 2003
----- --------------------
FirstEnergy Corp., $0.10 par value 297,636,276
Ohio Edison Company, no par value 100
The Cleveland Electric Illuminating Company, no par value 79,590,689
The Toledo Edison Company, $5 par value 39,133,887
FirstEnergy Corp. is the sole holder of Ohio Edison Company, The Cleveland
Electric Illuminating Company and The Toledo Edison Company.
Documents incorporated by reference (to the extent indicated herein):
PART OF FORM 10-K/A INTO WHICH
DOCUMENT DOCUMENT IS INCORPORTED
-------- -----------------------
FirstEnergy Corp. Annual Report to Stockholders for
the fiscal year ended December 31, 2002 (Pages 6-53) Part II
This combined Form 10-K/A is separately filed by FirstEnergy Corp.,
Ohio Edison Company, The Cleveland Electric Illuminating Company and The Toledo
Edison Company. Information contained herein relating to any individual
registrant is filed by such registrant on its own behalf. No registrant makes
any representation as to information relating to any other registrant, except
that information relating to any of the three FirstEnergy subsidiary registrants
is also attributed to FirstEnergy.
EXPLANATORY NOTE
As described in Note 2(M) to the consolidated financial statements of
First Energy Corp. and Note 1(M) to the consolidated financial statements of
Ohio Edison Company, the Registrants are restating their financial statements
for the year ended December 31, 2002. As described in Note 1(M) to the
consolidated financial statements of The Cleveland Electric Illuminating Company
and The Toledo Edison Company, these Registrants are restating their financial
statements for the three years ended December 31, 2002. The restatements
principally reflect a change in the method of amortizing the costs being
recovered under the Ohio transition plan and recognition of above-market values
of certain leased generation facilities. The Registrants are filing amended
Annual Reports on the Form 10-K/A to reflect the restatements.
THE FOLLOWING ITEMS HAVE BEEN AMENDED IN THIS AMENDMENT NO. 2:
PART I
ITEM 1. BUSINESS
PART II
ITEM 6. SELECTED FINANCIAL DATA
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
PART III
ITEM 14. CONTROLS AND PROCEDURES
PART IV
ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON
FORM 8-K
FORM 10-K/A
TABLE OF CONTENTS
PAGE
----
PART I
Item 1. Business.................................................................................... 1
Recent Developments....................................................................... 1
Environmental Matters................................................................... 1
Regulatory Matters...................................................................... 1
International Operations................................................................ 2
Other Matters........................................................................... 3
The Company............................................................................... 3
Divestitures.............................................................................. 4
International Operations................................................................ 3
Generating Assets....................................................................... 3
Utility Regulation........................................................................ 3
PUCO Rate Matters....................................................................... 4
NJBPU Rate Matters...................................................................... 4
PPUC Rate Matters....................................................................... 5
FERC Rate Matters....................................................................... 6
Regulatory Accounting................................................................... 7
Capital Requirements...................................................................... 7
Met-Ed Capital Trust and Penelec Capital Trust............................................ 9
Nuclear Regulation........................................................................ 9
Nuclear Insurance......................................................................... 10
Environmental Matters..................................................................... 11
Air Regulation.......................................................................... 11
Water Regulation........................................................................ 12
Waste Disposal.......................................................................... 12
Summary................................................................................. 12
Fuel Supply............................................................................... 13
System Capacity and Reserves.............................................................. 13
Regional Reliability...................................................................... 14
Competition............................................................................... 14
Research and Development.................................................................. 15
Executive Officers........................................................................ 15
FirstEnergy Website....................................................................... 15
Item 2. Properties.................................................................................. *
Item 3. Legal Proceedings........................................................................... *
Item 4. Submission of Matters to a Vote of Security Holders......................................... *
PART II
Item 5. Market for Registrant's Common Equity and Related Stockholder Matters....................... *
Item 6. Selected Financial Data..................................................................... 16
Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations....... 16
Item 8. Financial Statements and Supplementary Data................................................. 16
Item 9. Changes In and Disagreements with Accountants on Accounting and Financial Disclosure........ *
PART III
Item 10. Directors and Executive Officers of the Registrant.......................................... *
Item 11. Executive Compensation...................................................................... *
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related
Shareholder Matters....................................................................... *
Item 13. Certain Relationships and Related Transactions.............................................. *
Item 14. Controls and Procedures..................................................................... 16
PART IV
Item 15. Exhibits, Financial Statement Schedules and Reports on Form 8-K............................. 16
* Indicates the items that have not been revised and are not included in this
Form 10-K/A. Reference is made to the original 10-K for the complete text of
such items.
PART 1
ITEM 1. BUSINESS
RECENT DEVELOPMENTS
ENVIRONMENTAL MATTERS-
On August 8, 2003, FirstEnergy Corp. (FirstEnergy), Ohio Edison Company
(OE) and Pennsylvania Power Company (Penn) reported a development regarding a
complaint filed by the U.S. Department of Justice with respect to the W.H.
Sammis Plant (see Note 7(D) Commitments, Guarantees and Contingencies -
Environmental Matters). As reported, on August 7, 2003, the United States
District Court for the Southern District of Ohio ruled that 11 projects
undertaken at the Sammis Plant between 1984 and 1998 required pre-construction
permits under the Clean Air Act. The ruling concludes the liability phase of the
case, which deals with applicability of Prevention of Significant Deterioration
provisions of the Clean Air Act. The remedy phase, which is currently scheduled
to be ready for trial beginning March 15, 2004, will address civil penalties and
what, if any, actions should be taken to further reduce emissions at the plant.
In the ruling, the Court indicated that the remedies it "may consider and impose
involved a much broader, equitable analysis, requiring the Court to consider air
quality, public health, economic impact, and employment consequences. The Court
may also consider the less than consistent efforts of the EPA to apply and
further enforce the Clean Air Act." The potential penalties that may be imposed,
as well as the capital expenditures necessary to comply with substantive
remedial measures that may be required, may have a material adverse impact on
the Company's financial condition and results of operations. Management is
unable to predict the ultimate outcome of this matter.
REGULATORY MATTERS-
New Jersey
On July 25, 2003, FirstEnergy and Jersey Central Power & Light Company
(JCP&L)JCP&L announced that they are reviewing is underway concerning a decision
by the New Jersey Board of Public Utilities (NJBPU) on JCP&L's rate proceeding
(See Note 2(D)). Based on that review, JCP&L will decide its appropriate course
of action, which could include filing a request for reconsideration with the
NJBPU and possibly an appeal to the Appellate Division of the Superior Court of
New Jersey.
In its ruling, the NJBPU reduced JCP&L's annual revenues by
approximately $62 million, for an average rate decrease of 3 percent, effective
August 1, 2003. The NJBPU decision also provided for an interim return on equity
of 9.5 percent on JCP&L's rate base for the next 6 to 12 months. During that
period, JCP&L would initiate another proceeding to request recovery of
additional expenses incurred to enhance system reliability. In that proceeding,
the NJBPU could increase the return on equity to 9.75 percent or decrease it to
9.25 percent, depending on its assessment of the reliability of JCP&L's service.
Any reduction could be retroactive to August 1, 2003.
The NJBPU decision reflects elimination of $111 million in annual
customer credits mandated by the New Jersey Electric Discount and Energy
Competition Act (EDECA); a $223 million reduction in the energy delivery charge;
a net $1 million increase in the Societal Benefits Charge (SBC); and a $49
million increase in the Market Transition Charge (MTC). The $1 million net SBC
increase reflects approximately a $22 million increase related to universal
services costs previously approved in a separate proceeding, as well as
reductions in other components of the SBC.
The MTC would allow for the recovery of $465 million in deferred energy
costs over the next 10 years on an interim basis, thus disallowing $153 million
of the $618 million provided for in the settlement agreement. This decision
reflects the NJBPU's belief that a hindsight review comparing JCP&L's power
purchases to spot market prices provides the appropriate benchmark for recovery.
JCP&L's deferred energy costs primarily reflect mandated purchase power
contracts with NUGs that are above wholesale market prices, and costs of
providing basic generation service to customers in excess of the company's
capped basic generation service charges during the transition period under
EDECA, which ends August 1, 2003. At that time, the generation portion of most
customer bills will increase by an average of 7.5 percent as a result of the
outcome of the basic generation service auction conducted earlier this year by
the BPU.
In the second quarter of 2003, JCP&L recorded charges aggregating $158
million ($94 million after tax) consisting of the $153 million deferred energy
costs and other regulatory assets.
On July 25, 2003, the NJBPU approved a Stipulation of Settlement
between the parties and authorized the recovery of the total $135 million of the
Freehold buyout costs, eliminating the interim nature of the recovery.
1
Pennsylvania
On April 2, 2003, the Pennsylvania Public Utilities Commission (PPUC)
remanded the merger savings issue to the Office of Administrative Law Judge
(ALJ) and directed Met-Ed and Penelec to submit a position paper by May 2, 2003
on the status of the Settlement Stipulation in light of the Commonwealth Court's
decision (Court Order). In summary, Met-Ed and Penelec submitted to the PPUC the
following position:
- On January 16, 2003, the Pennsylvania Supreme Court denied or quashed
all appeals arising from the Court Order, thus rendering the Court
Order final.
- Because the parties sought request for a stay of the PPUC's June 20,
2001 order in which the Settlement Stipulation was approved, all terms
and conditions included therein that were not inconsistent with the
Court Order remained in effect.
- Only those provisions related to PLR cost recovery and PLR deferral
issues addressed by the PPUC and expressly rejected by the Commonwealth
Court, must be removed from the Settlement Stipulation.
- The GENCO Code of Conduct must be reinstated consistent with the Court
Order.
- All other provisions included in the Settlement Stipulation unrelated
to these three issues remain in effect.
On or about June 2, 2003, parties filed comments in response to the
position presented by Met-Ed and Penelec. The other parties' responses included
significant disagreement with the position paper and disagreement among the
other parties themselves, including the Stipulation's original signatory
parties. Some parties believe that no portion of the Stipulation has survived
the Commonwealth Court's Order. Based upon these comments, it became clear that
many of the parties not only disagreed with Met-Ed and Penelec, but also
disagreed among themselves. Partially because of this lack of consensus among
the parties, Met-Ed and Penelec submitted a letter on June 11, 2003, to the ALJ
informing the ALJ and all other parties that Met-Ed and Penelec were voiding the
Settlement Stipulation, pursuant to the termination provisions found therein.
Notwithstanding the voiding of the Settlement Stipulation, Met-Ed and Penelec
voluntarily agreed to retain virtually all of the customer benefits provided by
the Settlement Stipulation, including, among others, funding for renewable
energy resource and demand response programs. Met-Ed and Penelec also agreed to
cap distribution rates at current levels through 2007, provided that the PPUC
finds during the remanded merger saving proceedings that Met-Ed and Penelec have
satisfied the public interest test applicable to mergers and leave the
quantification of merger savings for a subsequent rate proceedings. They believe
this will significantly simplify the issues in the pending action by reinstating
Met-Ed's and Penelec's Restructuring Settlement previously approved by the PPUC.
In addition, they have agreed to voluntarily continue certain Stipulation
provisions including funding for energy and demand side response programs and to
cap distribution rates at current levels through 2007. This voluntary
distribution rate cap is contingent upon a finding that Met-Ed and Penelec have
satisfied the "public interest" test applicable to mergers and that any rate
impacts of merger savings will be dealt with in a subsequent rate case. Met-Ed
and Penelec believe that their actions in voiding the Settlement Stipulation
will simplify the issues and limit them to the treatment of merger savings and
whether Met-Ed's and Penelec's accounting is consistent with the Court Order.
INTERNATIONAL OPERATIONS-
Pending Sale of Remaining Investment in Avon and Sale of Note from Aquila
On May 22, 2003, FirstEnergy announced it reached an agreement to sell
its 20.1 percent interest in Avon to Scottish and Southern Energy plc; that
agreement also includes Aquila's 79.9 percent interest (See Note 3). Under terms
of the agreement, which is subject to bondholder approval, Scottish and
Southern will pay FirstEnergy and Aquila an aggregate $70 million (FirstEnergy's
share would be approximately $14 million). Avon's debt will remain with that
company. FirstEnergy recognized in the second quarter of 2003 an impairment of
$12.6 million ($8.2 million after tax) related to the carrying value of the note
receivable from the initial sale of a 79.9 percent interest in Avon that
occurred in May 2002. After receiving the first annual installment payment of
$19 million in May 2003, FirstEnergy sold the remaining balance of the note in
the secondary market and received $63.2 million in proceeds on July 28, 2003.
Emdersa
On April 18, 2003, FirstEnergy divested its ownership in Emdersa
through the abandonment of its shares in Emdersa's parent company, GPU Argentina
Holdings, Inc. The abandonment was accomplished by relinquishing FirstEnergy's
shares to the independent Board of Directors of GPU Argentina Holdings,
relieving FirstEnergy of all rights and obligations relative to this business.
As a result of the abandonment, FirstEnergy recognized a one-time, non-cash
charge of $67.4 million, or $0.23 per share of common stock in the second
quarter of 2003. This charge is the result of realizing the Currency Translation
Adjustment (CTA) losses through current period earnings ($89.8 million, or $0.30
per share), partially offset by the gain recognized from abandoning
FirstEnergy's investment in Emdersa ($22.4 million, or
2
$0.07 per share). Since FirstEnergy had previously recorded $90 million of CTA
adjustments in OCI, the net effect of the $67.4 million charge was an increase
in common stockholders' equity of $22.4 million.
The $67.4 million charge does not include the anticipated income tax
benefits related to the abandonment, which were fully reserved during the second
quarter. FirstEnergy anticipates tax benefits of approximately $129 million, of
which $50 million would increase net income in the period that it becomes
probable those benefits will be realized. The remaining $79 million of tax
benefits would reduce goodwill recognized in connection with the acquisition of
GPU. See note 2(M) to the FirstEnergy Consolidated Financial Statements for
discussion or classification of a discontinued operation in the Revised
Financial Statements.
OTHER MATTERS -
It is FirstEnergy's understanding that, as of August 18, 2003, five
individual shareholder-plaintiffs have filed separate complaints against
FirstEnergy Corp. alleging various securities law violations in connection with
the restatement of earnings described herein. Most of these complaints have not
yet been officially served on the Company. Moreover, FirstEnergy is still
reviewing the suits that have been served in preparation for a responsive
pleading. FirstEnergy is, however, aware that in each case, the plaintiffs are
seeking certification from the court to represent a class of similarly situated
shareholders.
On August 14, 2003, eight states in the Northeast U.S. and southern
Canada experienced a widespread power outage. That outage affected approximately
1.4 million customers in FirstEnergy's service area. The cause of the outage has
not been determined. Having restored service to its customers, FirstEnergy is
now in the process of accumulating data and evaluating the status of its
electrical system prior to and during the outage event and would expect that the
same effort is under way at utilities and regional transmission operators across
the region.
As of August 18, 2003, the following facts about FirstEnergy's system
were known. Early in the afternoon of August 14, hours before the event, Unit 5
of the Eastlake Plant in Eastlake, Ohio, tripped off. Later in the afternoon,
three FirstEnergy transmission lines and one owned by American Electric Power
and FirstEnergy tripped out of service. The Midwest Independent System Operator
(MISO), which oversees the regional transmission grid, indicated that there were
a number of other transmission line trips in the region outside of FirstEnergy's
system. FirstEnergy customers experienced no service interruptions resulting
from these conditions. Indications to FirstEnergy were that the Company's system
was stable. Therefore, no isolation of FirstEnergy's system was called for. In
addition, FirstEnergy determined that its computerized system for monitoring and
controlling its transmission and generation system was operating, but the alarm
screen function was not. However, MISO's monitoring system was operating
properly. FirstEnergy believes that extensive data needs to be gathered and
analyzed in order to determine with any degree of certainty the circumstances
that led to the outage. This a very complex situation, far broader than the
power line outages FirstEnergy experienced on its system. From the preliminary
data that has been gathered, FirstEnergy believes that the transmission grid in
the Eastern Interconnection, not just within FirstEnergy's system, was
experiencing unusual electrical conditions at various times prior to the event.
These included unusual voltage and frequency fluctuations and load swings on the
grid. FirstEnergy is committed to working with the North American Electric
Reliability Council and others involved to determine exactly what events in the
entire affected region led to the outage. There is no timetable as to when this
entire process will be completed. It is, however, expected to last several
weeks, at a minimum.
THE COMPANY
FirstEnergy Corp. was organized under the laws of the State of Ohio in
1996. FirstEnergy's principal business is the holding, directly or indirectly,
of all of the outstanding common stock of its principal electric utility
operating subsidiaries, Ohio Edison Company (OE), The Cleveland Electric
Illuminating Company (CEI), Pennsylvania Power Company (Penn), The Toledo Edison
Company (TE), American Transmission Systems, Incorporated (ATSI), Jersey Central
Power & Light Company (JCP&L), Metropolitan Edison Company (Met-Ed) and
Pennsylvania Electric Company (Penelec). These utility subsidiaries are referred
to throughout as "Companies." FirstEnergy's consolidated revenues are primarily
derived from electric service provided by its utility operating subsidiaries and
the revenues of its other principal subsidiaries: FirstEnergy Solutions Corp.
(FES); FirstEnergy Facilities Services Group, LLC (FSG); MYR Group Inc. (MYR);
MARBEL Energy Corporation (MARBEL); GPU Capital, Inc.; and GPU Power, Inc. In
addition, FirstEnergy holds all of the outstanding common stock of other direct
subsidiaries including: FirstEnergy Properties, Inc., FirstEnergy Ventures
Corp., FirstEnergy Nuclear Operating Company (FENOC), FirstEnergy Securities
Transfer Company, GPU Diversified Holdings, LLC, GPU Telecom Services, Inc., GPU
Nuclear, Inc.; FirstEnergy Service Company (FECO); GPU Service, Inc. (GPUS); and
GPU Advanced Resources, Inc.
The Companies' combined service areas encompass approximately 37,200
square miles in Ohio, New Jersey and Pennsylvania. The areas they serve have a
combined population of approximately 11.1 million.
OE was organized under the laws of the State of Ohio in 1930 and owns
property and does business as an electric public utility in that state. OE also
has ownership interests in certain generating facilities located in the
Commonwealth of Pennsylvania (see Item 2 - Properties). OE engages in the
generation, distribution and sale of electric energy to communities in a 7,500
square mile area of central and northeastern Ohio. OE also engages in the sale,
3
purchase and interchange of electric energy with other electric companies. The
area it serves has a population of approximately 2.7 million.
OE owns all of Penn's outstanding common stock. Penn was organized
under the laws of the Commonwealth of Pennsylvania in 1930 and owns property and
does business as an electric public utility in that state. Penn is also
authorized to do business and owns property in the State of Ohio (see Item 2 -
Properties). Penn furnishes electric service to communities in a 1,500 square
mile area of western Pennsylvania. The area served by Penn has a population of
approximately 0.3 million.
CEI was organized under the laws of the State of Ohio in 1892 and does
business as an electric public utility in that state. CEI engages in the
generation, distribution and sale of electric energy in an area of approximately
1,700 square miles in northeastern Ohio. It also has ownership interests in
certain generating facilities in Pennsylvania (see Item 2 - Properties). CEI
also engages in the sale, purchase and interchange of electric energy with other
electric companies. The area CEI serves has a population of approximately 1.9
million.
TE was organized under the laws of the State of Ohio in 1901 and does
business as an electric public utility in that state. TE engages in the
generation, distribution and sale of electric energy in an area of approximately
2,500 square miles in northwestern Ohio. It also has interests in certain
generating facilities in Pennsylvania and Michigan (see Item 2 - Properties). TE
also engages in the sale, purchase and interchange of electric energy with other
electric companies. The area TE serves has a population of approximately 0.8
million.
ATSI was organized under the laws of the State of Ohio in 1998. ATSI
owns transmission assets that were formerly owned by OE, CEI and TE (Ohio
Companies) and Penn. ATSI owns and operates major, high-voltage transmission
facilities, which consist of approximately 7,100 circuit miles (5,778 pole
miles) of transmission lines with nominal voltages of 345 kilovolts (kV), 138 kV
and 69 kV. There are 37 interconnections with six neighboring control areas.
ATSI's transmission system offers gateways into the East through high capacity
ties with Pennsylvania-New Jersey-Maryland Interconnection LLC (PJM) through
Penelec, Duquesne Light Company (Duquesne) and Allegheny Energy, Inc.
(Allegheny), into the North through multiple 345 kV high capacity ties with
Michigan Electric Coordination Systems (MEC), and into the South through ties
with American Electric Power Company, Inc. (AEP) and Dayton Power & Light
Company (DPL). In addition, ATSI is the control area operator for the Ohio
Companies and Penn service areas. ATSI plans, operates and maintains the
transmission system in accordance with the requirements of the North American
Electric Reliability Council and applicable regulatory agencies to ensure
reliable service to FirstEnergy's customers (see FERC Rate Matters for
discussion on ATSI's participation in the Midwest Independent System Operator,
Inc. (MISO)).
JCP&L was organized under the laws of the State of New Jersey in 1925
and owns property and does business as an electric public utility in that state.
JCP&L provides transmission and distribution services in northern, western and
east central New Jersey. The area it serves has a population of approximately
2.5 million.
Met-Ed was organized under the laws of the Commonwealth of Pennsylvania
in 1922 and owns property and does business as an electric public utility in
that state. Met-Ed provides transmission and distribution services in eastern
and south central Pennsylvania. The area it serves has a population of
approximately 1.1 million.
Penelec was organized under the laws of the Commonwealth of
Pennsylvania in 1919 and owns property and does business as an electric public
utility in that state. Penelec provides transmission and distribution services
in western, northern and south central Pennsylvania. The area it serves has a
population of approximately 1.7 million. Penelec, as lessee of the property of
its subsidiary, The Waverly Electric Light & Power Company, also serves a
population of about 13,400 in Waverly, New York and vicinity.
FES was organized under the laws of the State of Ohio in 1997 and
provides energy-related products and services, and through its FirstEnergy
Generation Corp. (FGCO) subsidiary, operates FirstEnergy's nonnuclear generation
businesses. FSG is the parent company of several heating, ventilating, air
conditioning and energy management companies; MYR is a utility infrastructure
construction service company. MARBEL is a natural gas pipeline company whose
subsidiaries include MARBEL HoldCo, Inc. a holding company having a 50%
ownership interest in Great Lakes Energy Partners, LLC, an oil and natural gas
exploration and production venture, and Northeast Ohio Natural Gas Corp., a
public utility that provides gas distribution and transportation services. GPU
Capital owns and operates electric distribution systems in foreign countries and
GPU Power owns and operates generation facilities in foreign countries. FECO and
GPUS provide legal, financial and other corporate support services to affiliated
FirstEnergy companies.
DIVESTITURES
International Operations
FirstEnergy identified certain former GPU international operations for
divestiture within one year of its merger with GPU, Inc. on November 7, 2001.
These operations constitute individual "lines of business" as defined in
Accounting Principles Board Opinion (APB) No. 30, "Reporting the Results of
Operations - Reporting the Effects of Disposal of a
4
Segment of a Business, and Extraordinary, Unusual and Infrequently Occurring
Events and Transactions," with physically and operationally separable
activities. Application of Emerging Issues Task Force (EITF) Issue No. 87-11,
"Allocation of Purchase Price to Assets to Be Sold," required that expected,
pre-sale cash flows, including incremental interest costs on related acquisition
debt, of these operations be considered part of the purchase price allocation.
Accordingly, subsequent to the merger date, results of operations and
incremental interest costs related to these international subsidiaries were not
included in FirstEnergy's 2001 Consolidated Statements of Income. Additionally,
assets and liabilities of these international operations were segregated under
separate captions on the Consolidated Balance Sheet as of December 31, 2001 as
"Assets Pending Sale" and "Liabilities Related to Assets Pending Sale."
Upon completion of its merger with GPU, FirstEnergy accepted an October
2001 offer from Aquila, Inc. (formerly UtiliCorp United) to purchase Avon Energy
Partners Holdings (Avon), FirstEnergy's wholly owned holding company for
Midlands Electricity plc, for $2.1 billion (including the assumption of $1.7
billion of debt). The transaction closed on May 8, 2002 and reflected the March
2002 modification of Aquila's initial offer such that Aquila acquired a 79.9
percent equity interest in Avon for approximately $1.9 billion (including the
assumption of $1.7 billion of debt). Proceeds to FirstEnergy included $155
million in cash and a note receivable for approximately $87 million
(representing the present value of $19 million per year to be received over six
years beginning in 2003) from Aquila for its 79.9 percent interest. FirstEnergy
and Aquila together own all of the outstanding shares of Avon through a jointly
owned subsidiary, with each company having an ownership voting interest.
Originally, in accordance with applicable accounting guidance, the earnings of
those foreign operations were not recognized in current earnings from the date
of the GPU acquisition. However, as a result of the decision to retain an
ownership interest in Avon, EITF Issue No. 90-6, "Accounting for Certain Events
Not Addressed in Issue No. 87-11 relating to an Acquired Operating Unit to be
Sold" required FirstEnergy to reallocate the purchase price of GPU based on
amounts as of the purchase date as if Avon had never been held for sale,
including reversal of the effects of having applied EITF Issue No. 87-11, to the
transaction. The effect of reallocating the purchase price and reversal of the
effects of EITF Issue No. 87-11, including the allocation of capitalized
interest, has been reflected in the Consolidated Statement of Income for the
year ended December 31, 2002 by reclassifying certain revenue and expense
amounts related to activity during the quarter ended March 31, 2002 to their
respective income statement classifications. See Note 2(L) of Notes to
FirstEnergy's Consolidated Financial Statements for the effects of the change in
classification. In the fourth quarter of 2002, FirstEnergy recorded a $50
million charge ($32.5 million net of tax) to reduce the carrying value of its
remaining 20.1 percent interest.
GPU's former Argentina operations were also identified by FirstEnergy
for divestiture within one year of the merger. FirstEnergy determined the fair
value of its Argentina operations, GPU Empresa Distribuidora Electrica Regional
S.A. and affiliates (Emdersa), based on the best available information as of the
date of the merger. Subsequent to that date, a number of economic events have
occurred in Argentina which may have an impact on FirstEnergy's ability to
realize Emdersa's estimated fair value. These events include currency
devaluation, restrictions on repatriation of cash, and the anticipation of
future asset sales in that region by competitors. FirstEnergy did not reach a
definitive agreement to sell Emdersa as of December 31, 2002. Therefore, these
assets were no longer classified as "Assets Pending Sale" on the Consolidated
Balance Sheet as of December 31, 2002 and Emdersa's results of operations were
included in FirstEnergy's 2002 Consolidated Statement of Income. Additionally,
under EITF Issue No. 90-6, FirstEnergy recorded in the fourth quarter of 2002 a
one-time, non-cash charge included as a "Cumulative Adjustment for Retained
Businesses Previously Held for Sale" on its 2002 Consolidated Statement of
Income related to Emdersa's cumulative results of operations from November 7,
2001 through September 30, 2002. The amount of this one-time, after-tax charge
was $93.7 million, or $0.32 per share of common stock (comprised of $108.9
million in currency transaction losses arising principally from U.S. dollar
denominated debt, offset by $15.2 million of operating income). See Note 2(L) of
Notes to First Energy's Consolidated Financial Statements for the effects of the
change in classification.
On October 1, 2002, FirstEnergy began consolidating the results of
Emdersa's operations in its financial statements. In addition to the currency
transaction losses of $108.9 million, FirstEnergy recognized a currency
translation adjustment (CTA) in other comprehensive income (OCI) of $91.5
million as of December 31, 2002, which reduced FirstEnergy's common
stockholders' equity. This adjustment represents the impact of translating
Emdersa's financial statements from its functional currency to the U.S. dollar
for financial reporting in conformity with accounting principles generally
accepted in the United States (GAAP).
On April 18, 2003, FirstEnergy divested its ownership in Emdersa
through the abandonment of its shares in Emdersa's parent company, GPU Argentina
Holdings, Inc. The abandonment was accomplished by relinquishing FirstEnergy's
shares to the independent Board of Directors of GPU Argentina Holdings,
relieving FirstEnergy of all rights and obligations relative to this business.
As a result of the abandonment, FirstEnergy will recognize a one-time, non-cash
charge of $63 million, or $0.21 per share of common stock in the second quarter
of 2003. This charge is the result of realizing the CTA losses through the
current period earnings ($90 million, or $0.30 per share), partially offset by
the gain recognized from eliminating its investment in Emdersa ($27 million, or
$0.09 per share). Since FirstEnergy has previously recorded $90 million of CTA
adjustments in OCI, the net effect of the $63 million charge will be an increase
in common stockholders' equity of $27 million.
The $63 million charge does not include the anticipated income tax
benefits related to the abandonment. These tax benefits will be fully reserved
during the second quarter. FirstEnergy anticipates tax benefits of approximately
5
$129 million, of which $50 million would increase net income in the period that
it becomes probable those benefits will be realized. The remaining $79 million
tax benefits would reduce goodwill recognized in connection with the acquisition
of GPU.
Generating Assets
In November 2001, FirstEnergy reached an agreement to sell four
coal-fired power plants totaling 2,535 megawatts (MW) to NRG Energy Inc. On
August 8, 2002, FirstEnergy notified NRG that it was canceling the agreement
because NRG stated that it could not complete the transaction under the original
terms of the agreement. FirstEnergy also notified NRG that FirstEnergy reserves
the right to pursue legal action against NRG, its affiliate and its parent, Xcel
Energy, for damages, based on the anticipatory breach of the agreement. NRG
declared bankruptcy on February 25, 2003, the U.S. Bankruptcy Court in Minnesota
approved FirstEnergy's request for arbitration against NRG.
In December 2002, FirstEnergy announced it would retain ownership of
these plants after reviewing bids received from other bids received from other
parties who had expressed interest in purchasing the plants. Since FirstEnergy
did not execute a sales agreement by year-end, it reflected approximately $74
million ($43 million net of tax), or $0.15 per share of common stock, of
previously unrecognized depreciation and transaction costs in the fourth quarter
of 2002 related to these plants from November 2001 through December 2002 on its
Consolidated Statement of Income.
UTILITY REGULATION
As a registered public utility holding company, FirstEnergy is subject
to regulation by the Securities and Exchange Commission (SEC) under the Public
Utility Holding Company Act of 1935 (1935 Act). The SEC has determined that the
electric facilities of the Companies constitute a single integrated public
utility system under the standards of the 1935 Act. The 1935 Act regulates
FirstEnergy with respect to accounting, the issuance of securities, the
acquisition and sale of utility assets, securities or any other interest in any
business, and entering into, and performance of, service, sales and construction
contracts among its subsidiaries, and certain other matters. The 1935 Act also
limits the extent to which FirstEnergy may engage in nonutility businesses or
acquire additional utility businesses. Each of the Companies' retail rates,
conditions of service, issuance of securities and other matters are subject to
regulation in the state in which each operates - in Ohio by the Public Utilities
Commission of Ohio (PUCO), in New Jersey by the New Jersey Board of Public
Utilities (NJBPU) and in Pennsylvania by the Pennsylvania Public Utility
Commission (PPUC). With respect to their wholesale and interstate electric
operations and rates, the Companies are subject to regulation, including
regulation of their accounting policies and practices, by the Federal Energy
Regulatory Commission (FERC). Under Ohio law, municipalities may regulate rates,
subject to appeal to the PUCO if not acceptable to the utility.
In Ohio, New Jersey and Pennsylvania, laws applicable to electric
industry deregulation included the similar provisions which are reflected in the
Companies' respective state regulatory plans:
- allowing the Companies' electric customers to select their
generation suppliers;
- establishing provider of last resort (PLR) obligations to
customers in the Companies' service areas;
- allowing recovery of potentially stranded investment (sometimes
referred to as transition costs);
- itemizing (unbundling) the current price of electricity into its
component elements - including generation, transmission,
distribution and stranded costs recovery charges;
- deregulating the Companies' electric generation businesses; and
- continuing regulation of the Companies' transmission and
distribution systems.
PUCO Rate Matters
In July 1999, Ohio's electric utility restructuring legislation, which
allowed Ohio electric customers to select their generation suppliers beginning
January 1, 2001, was signed into law. Among other things, the legislation
provided for a 5% reduction on the generation portion of residential customers'
bills and the opportunity to recover transition costs, including regulatory
assets, from January 1, 2001 through December 31, 2005 (market development
period). The period for the recovery of regulatory assets only can be extended
up to December 31, 2010. The PUCO was authorized to determine the level of
transition cost recovery, as well as the recovery period for the regulatory
assets portion of those costs, in considering each Ohio electric utility's
transition plan application.
In July 2000, the PUCO approved FirstEnergy's transition plan for the
OE, CEI and TE (Ohio Companies) as modified by a settlement agreement with major
parties to the transition plan. The application of SFAS 71, "Accounting for the
Effects of Certain Types of Regulation," to OE's generation business and the
nonnuclear generation businesses of CEI and TE was discontinued with the
issuance of the PUCO transition plan order, as described further below. Major
provisions of the settlement agreement consisted of approval of recovery of
generation-related transition costs as filed of
6
$4.0 billion, net of deferred income taxes (OE-$1.6 billion, CEI-$1.6 billion
and TE-$0.8 billion), and transition costs related to regulatory assets as filed
of $2.9 billion, net of deferred income taxes (OE-$1.0 billion, CEI-$1.4 billion
and TE-$0.5 billion), with recovery through no later than 2006 for OE, mid-2007
for TE and 2008 for CEI, except where a longer period of recovery is provided
for in the settlement agreement. The generation-related transition costs include
$1.4 billion, net of deferred income taxes (OE-$1.0 billion, CEI-$0.2 billion
and TE-$0.2 billion), of impaired generating assets recognized as regulatory
assets as described further below, $2.4 billion, net of deferred income taxes,
(OE-$1.2 billion, CEI-$0.4 billion and TE-$0.8 billion), of above-market
operating lease costs and $0.8 billion, net of deferred income taxes (CEI-$0.5
billion and TE-$0.3 billion), of additional plant costs that were reflected on
CEI's and TE's regulatory financial statements.
Also as part of the settlement agreement, FirstEnergy is giving
preferred access over its subsidiaries to nonaffiliated marketers, brokers and
aggregators to 1,120 megawatts (MW) of generation capacity through 2005 at
established prices for sales to the Ohio Companies' retail customers. Customer
prices are frozen through the five-year market development period except for
certain limited statutory exceptions, including the 5% reduction referred to
above. In February 2003, the Ohio Companies were authorized increases in annual
revenues aggregating approximately $50 million (OE-$41 million, CEI-$4 million
and TE-$5 million) to recover their higher tax costs resulting from the Ohio
deregulation legislation.
FirstEnergy's Ohio customers choosing alternative suppliers receive an
additional incentive applied to the shopping credit (generation component) of
45% for residential customers, 30% for commercial customers and 15% for
industrial customers. The amount of the incentive is deferred for future
recovery from customers - recovery will be accomplished by extending the
respective transition cost recovery period. If the customer shopping goals
established in the agreement had not been achieved by the end of 2005, the
transition cost recovery periods could have been shortened for OE, CEI and TE to
reduce recovery by as much as $500 million (OE - $250 million, CEI - $170
million and TE - $80 million). The Ohio Companies achieved all of their required
20% customer shopping goals in 2002. Accordingly, FirstEnergy believes that
there will be no regulatory action reducing the recoverable transition costs.
NJBPU Rate Matters
JCP&L's 2001 Final Decision and Order (Final Order) with respect to its
rate unbundling, stranded cost and restructuring filings confirmed rate
reductions set forth in its 1999 Summary Order, which remain in effect at
increasing levels through July 2003. The Final Order also confirmed the
establishment of a non-bypassable societal benefits charge (SBC) to recover
costs which include nuclear plant decommissioning and manufactured gas plant
remediation, as well as a non-bypassable market transition charge (MTC)
primarily to recover stranded costs. The NJBPU has deferred making a final
determination of the net proceeds and stranded costs related to prior generating
asset divestitures until JCP&L's request for an Internal Revenue Service (IRS)
ruling regarding the treatment of associated federal income tax benefits is
acted upon. Should the IRS ruling support the return of the tax benefits to
customers, there would be no effect to FirstEnergy's or JCP&L's net income since
the contingency existed prior to the merger with GPU.
In addition, the Final Order provided for the ability to securitize
stranded costs associated with the divested Oyster Creek Nuclear Generating
Station. In February 2002, JCP&L received NJBPU authorization to issue $320
million of transition bonds to securitize the recovery of these costs. The NJBPU
order also provided for a usage-based non-bypassable transition bond charge and
for the transfer of the bondable transition property to another entity. JCP&L
sold $320 million of transition bonds through its wholly owned subsidiary, JCP&L
Transition Funding LLC, in June 2002 - those bonds are recognized on the
Consolidated Balance Sheet.
JCP&L's PLR obligation to provide basic generation service (BGS) to
non-shopping customers is supplied almost entirely from contracted and open
market purchases. JCP&L is permitted to defer for future collection from
customers the amounts by which its costs of supplying BGS to non-shopping
customers and costs incurred under nonutility generation (NUG) agreements exceed
amounts collected through BGS and MTC rates. As of December 31, 2002, the
accumulated deferred cost balance totaled approximately $549 million. The NJBPU
also allowed securitization of JCP&L's deferred balance to the extent permitted
by law upon application by JCP&L and a determination by the NJBPU that the
conditions of the New Jersey restructuring legislation are met. There can be no
assurance as to the extent, if any, that the NJBPU will permit such
securitization.
Under New Jersey transition legislation, all electric distribution
companies were required to file rate cases to determine the level of unbundled
rate components to become effective August 1, 2003. On August 1, 2002, JCP&L
submitted two rate filings with the NJBPU. The first filing requested increases
in base electric rates of approximately $98 million annually. The second filing
was a request to recover deferred costs that exceeded amounts being recovered
under the current MTC and SBC rates; one proposed method of recovery of these
costs is the securitization of the deferred balance. This securitization
methodology is similar to the Oyster Creek securitization discussed above.
Hearings began in February 2003. On March 18, 2003, a report prepared by
independent auditors addressing costs deferred by JCP&L from August 1, 1999
through July 31, 2002, was transmitted to the Office of Administrative Law,
where JCP&L's rate case is being heard. While the auditors concluded that
JCP&L's energy procurement strategy and process was reasonable and prudent, they
identified potential disallowances totaling $17.3 million. The report subjected
$436 million
7
of deferred costs to a retrospective prudence review during a period of extreme
price uncertainty and volatility in the energy markets. Although JCP&L disagrees
with the potential disallowances, it is pleased with the report's major
conclusions and overall tone. Hearings concluded on April 28, 2003, and initial
briefs were filed on May 7, 2003. The Administrative Law Judge's recommended
decision is due by the end of June 2003 and the NJBPU's subsequent decision is
due in July 2003.
In 1997, the NJBPU authorized JCP&L to recover from customers, subject
to possible refund, $135 million of costs incurred in connection with a 1996
buyout of a power purchase agreement. JCP&L has recovered the full $135 million;
the NJBPU has established a procedural schedule to take further evidence with
respect to the buyout to enable it to make a final prudence determination
contemporaneously with the resolution of the pending rate case.
In December 2001, the NJBPU authorized the auctioning of BGS for the
period from August 1, 2002 through July 31, 2003 to meet the electricity demands
of all customers who have not selected an alternative supplier. The auction
results were approved by the NJBPU in February 2002, removing JCP&L's BGS
obligation of 5,100 MW for the period August 1, 2002 through July 31, 2003. In
February 2003, the NJBPU approved the BGS auction results for the period
beginning August 1, 2003. The auction covered a fixed price bid (applicable to
all residential and smaller commercial and industrial customers) and an hourly
price bid (applicable to all large industrial customers) process. JCP&L will
sell all self-supplied energy (NUGs and owned generation) to the wholesale
market with offsets to its deferred energy balances.
PPUC Rate Matters
The PPUC authorized 1998 rate restructuring plans for Penn, Met-Ed and
Penelec. In 2000, the PPUC disallowed a portion of the requested additional
stranded costs above those amounts granted in Met-Ed's and Penelec's 1998 rate
restructuring plan orders. The PPUC required Met-Ed and Penelec to seek an IRS
ruling regarding the return of certain unamortized investment tax credits and
excess deferred income tax benefits to customers. Similar to JCP&L's situation,
if the IRS ruling ultimately supports returning these tax benefits to customers,
there would be no effect to FirstEnergy's, Met-Ed's or Penelec's net income
since the contingency existed prior to the merger.
As a result of their generating asset divestitures, Met-Ed and Penelec
obtained their supply of electricity to meet their PLR obligations almost
entirely from contracted and open market purchases. In 2000, Met-Ed and Penelec
filed a petition with the PPUC seeking permission to defer, for future recovery,
energy costs in excess of amounts reflected in their capped generation rates;
the PPUC subsequently consolidated this petition in January 2001 with the
FirstEnergy/GPU merger proceeding.
In June 2001, the PPUC entered orders approving the Settlement
Stipulation with all of the major parties in the combined merger and rate relief
proceedings which approved the merger and provided Met-Ed and Penelec PLR
deferred accounting treatment for energy costs. The PPUC permitted Met-Ed and
Penelec to defer for future recovery the difference between their actual energy
costs and those reflected in their capped generation rates, retroactive to
January 1, 2001. Correspondingly, in the event that energy costs incurred by
Met-Ed and Penelec would be below their respective capped generation rates, that
difference would have reduced costs that had been deferred for recovery in
future periods. This PLR deferral accounting procedure was denied in a court
decision discussed below. Met-Ed's and Penelec's PLR obligations extend through
December 31, 2010; during that period competitive transition charge (CTC)
revenues would have been applied to their stranded costs. Met-Ed and Penelec
would have been permitted to recover any remaining stranded costs through a
continuation of the CTC after December 31, 2010 through no later than December
31, 2015. Any amounts not expected to be recovered by December 31, 2015 would
have been written off at the time such nonrecovery became probable.
Several parties had filed Petitions for Review in June and July 2001
with the Commonwealth Court of Pennsylvania regarding the June 2001 PPUC orders.
On February 21, 2002, the Court affirmed the PPUC decision regarding the
FirstEnergy/GPU merger, remanding the decision to the PPUC only with respect to
the issue of merger savings. The Court reversed the PPUC's decision regarding
the PLR obligations of Met-Ed and Penelec, and rejected those parts of the
settlement that permitted the companies to defer for accounting purposes the
difference between their wholesale power costs and the amount that they collect
from retail customers. FirstEnergy and the PPUC each filed a Petition for
Allowance of Appeal with the Pennsylvania Supreme Court on March 25, 2002,
asking it to review the Commonwealth Court decision. Also on March 25, 2002,
Citizens Power filed a motion seeking an appeal of the Commonwealth Court's
decision to affirm the FirstEnergy and GPU merger with the Pennsylvania Supreme
Court. In September 2002, FirstEnergy established reserves for Met-Ed's and
Penelec's PLR deferred energy costs which aggregated $287.1 million. The
reserves reflected the potential adverse impact of a pending Pennsylvania
Supreme Court decision whether to review the Commonwealth Court ruling.
FirstEnergy recorded an aggregate non-cash charge to income of $55.8 million
($32.6 million net of tax), or $0.11 per share of common stock, for the deferred
costs incurred subsequent to the merger. The reserve for the remaining $231.3
million of deferred costs increased goodwill by an aggregate net of tax amount
of $135.3 million.
On January 17, 2003, the Pennsylvania Supreme Court denied further
appeals of the February 21, 2002 Pennsylvania Commonwealth Court decision, which
effectively affirmed the PPUC's order approving the merger between
8
FirstEnergy and GPU, let stand the Commonwealth Court's denial of PLR rate
relief for Met-Ed and Penelec and remanded the merger savings issue back to the
PPUC. Because FirstEnergy had already reserved for the deferred energy costs and
FES has largely hedged the anticipated PLR energy supply requirements for Met-Ed
and Penelec through 2005 as discussed further below, FirstEnergy, Met-Ed and
Penelec believe that the disallowance of continued CTC recovery of PLR costs
will not have a material adverse financial impact.
Effective September 1, 2002, Met-Ed and Penelec assigned their PLR
responsibility to their FES affiliate through a wholesale power sale agreement.
The PLR sale, which initially ran through the end of 2002, was extended through
December 2003 and will be automatically extended for each successive calendar
year unless any party elects to cancel the agreement by November 1 of the
preceding year. Under the terms of the wholesale agreement, FES assumes the
supply obligation and the energy supply profit and loss risk for the portion of
power supply requirements not self-supplied by Met-Ed and Penelec under their
NUG contracts and other existing power contracts with nonaffiliated third party
suppliers. This arrangement reduces Met-Ed's and Penelec's exposure to high
wholesale power prices by providing power at or below the shopping credit for
their uncommitted PLR energy costs during the term of the agreement with FES.
FES has hedged most of Met-Ed's and Penelec's unfilled PLR obligation through
2005, the period during which deferred accounting was previously allowed under
the PPUC's order. Met-Ed and Penelec are authorized to continue deferring
differences between NUG contract rates and the rates reflected in their capped
generation rates.
FERC Rate Matters
The Companies provide wholesale power and transmission service subject
to the jurisdiction of the FERC.
Following the FirstEnergy/GPU merger the transmission facilities of
JCP&L, Met-Ed and Penelec continue to be operated by PJM. PJM was approved by
the FERC as a regional transmission organization (RTO) on December 20, 2002.
Transmission service over the facilities of FirstEnergy's PJM operating
companies is provided under the PJM Open Access Tariff.
On December 20, 2001, the FERC issued an order that reversed prior
findings that the Alliance RTO had adequate scope and concluded that there
should be only one RTO (the Midwest ISO) in the Midwest. The FERC directed the
former Alliance companies, including ATSI, to file their new RTO choices with
the FERC. On July 31, 2002, the FERC approved the RTO choices of the former
Alliance companies, but directed the formation of a single market for the MISO
and PJM by October 1, 2004. This single market would include all of the
generation and transmission facilities of the FirstEnergy operating companies.
FERC also initiated an investigation pursuant to Section 206 of the Federal
Power Act concerning the existing "through and out" transmission rates between
the MISO and PJM. Hearings on this proceeding concluded in January 2003, and an
Initial Decision is expected from the Administrative Law Judge by March 28,
2003.
ATSI proposes to transfer its transmission facilities in the East
Central Area Reliability Agreement (ECAR) area to the MISO RTO as part of
GridAmerica, LLC, an independent transmission company. On December 19, 2002, the
FERC conditionally accepted GridAmerica's filing to become an independent
transmission company within the MISO. GridAmerica will operate ATSI's
transmission facilities and expects to begin operations in the second quarter of
2003 subject to approval of certain compliance filings with the FERC. The
compliance filings were made by the GridAmerica companies (ATSI, Ameren Services
Company and Northern Indiana Public Service Company) on January 31, 2003 and
February 19, 2003.
On July 31, 2002, the FERC initiated a rulemaking designed to
standardize the terms and conditions under which wholesale electric service is
provided in regions with independent transmission operators, including the MISO
and PJM. FirstEnergy filed comments and reply comments on the proposed rule.
Implementation of the proposed rule was expected to begin on July 31, 2003.
However, the FERC has indicated that it will delay implementation of Standard
Market Design in order to accommodate substantial changes in the proposed rule.
A FERC "white paper" is expected to be issued in April 2003 outlining changes in
the proposed rule.
Regulatory Accounting
All of the Companies' regulatory assets (deferred costs) are expected
to continue to be recovered under provisions of the Ohio transition plan and the
respective Pennsylvania and New Jersey regulatory plans. The application of
Statement of Financial Accounting Standards (SFAS) No. 71, "Accounting for the
Effects of Certain Types of Regulation" (SFAS 71), has been discontinued with
respect to the Companies' generation operations.
CAPITAL REQUIREMENTS
Capital expenditures for the Companies, FES and FirstEnergy's other
subsidiaries for the years 2002 through 2007, excluding nuclear fuel, are shown
in the following table. Such costs include expenditures for the betterment of
existing facilities and for the construction of generating capacity, facilities
for environmental compliance, transmission lines, distribution lines,
substations and other assets. See "Environmental Matters" below with regard to
possible environmental-related expenditures not included in the forecast.
9
CAPITAL EXPENDITURES FORECAST
2002 --------------------------------------
ACTUAL 2003 2004-2007 TOTAL
------ ------ --------- ------
(IN MILLIONS)
OE $ 81 $ 86 $ 182 $ 268
Penn 40 53 70 123
CEI 137 96 216 312
TE 91 54 115 169
JCP&L 100 102 360 462
Met-Ed 43 53 235 288
Penelec 49 54 274 328
ATSI 27 25 106 131
FES 185 124 699 823
Other subsidiaries . 151 80 67 147
------ ------ ------ ------
Total $ 904 $ 727 $2,324 $3,051
During the 2003-2007 period, maturities of, and sinking fund
requirements for, long-term debt and preferred stock of FirstEnergy and its
subsidiaries are:
PREFERRED STOCK AND LONG-TERM DEBT
REDEMPTION SCHEDULE
--------------------------------------------
2003 2004-2007 TOTAL
------ --------- ------
(IN MILLIONS)
OE.............................. $ 210 $ 207 $ 417
Penn............................ 42 52 94
CEI............................. 146 704 850
TE.............................. 116 245 361
JCP&L........................... 174 510 684
Met-Ed.......................... 60 292 352
Penelec......................... -- 137 137
FirstEnergy..................... -- 1,695 1,695
Other subsidiaries.............. 327 40 367
------ ------ ------
Total........................... $1,075 $3,882 $4,957
The Companies' and FES's respective investments for additional nuclear fuel, and
nuclear fuel investment reductions as the fuel is consumed, during the 2003-2007
period are presented in the following table. The table also displays the
Companies' operating lease commitments, net of capital trust cash receipts for
the 2003-2007 period.
NUCLEAR FUEL FORECASTS
----------------------------------------------------------------- NET
NEW INVESTMENTS CONSUMPTION OPERATING LEASE COMMITMENTS
----------------------------- ----------------------------- ------------------------------
2003 2004-2007 TOTAL 2003 2004-2007 TOTAL 2003 2004-2007 TOTAL
----- --------- ----- ----- --------- ----- ----- --------- -----
(IN MILLIONS)
OE $ 23 $ 32 $ 55 $ 24 $ 27 $ 51 $ 74 $ 321 $ 395
Penn 19 23 42 17 17 34 -- 1 1
CEI 15 38 53 28 31 59 (2) 70 68
TE 12 22 34 19 21 40 75 311 386
JCP&L -- -- -- -- -- -- 3 6 9
Met-Ed -- -- -- -- -- -- 3 5 8
FES -- 301 301 -- 299 299 -- -- --
----- ----- ----- ----- ----- ----- ----- ----- -----
Total $ 69 $ 416 $ 485 $ 88 $ 395 $ 483 $ 153 $ 714 $ 867
Short-term borrowings outstanding as of December 31, 2002, consisted of
$1.093 billion of bank borrowings (FirstEnergy-$910.0 million, OE-$22.6 million
and FSG-$0.5 million) and $159.7 million of OES Capital, Incorporated commercial
paper. OES Capital is a wholly owned subsidiary of OE whose borrowings are
secured by customer accounts receivable. OES Capital can borrow up to $170
million under a receivables financing agreement at rates based on certain bank
commercial paper. FirstEnergy had $177 million available under $1.5 billion of
revolving lines of credit as of December 31, 2002. FirstEnergy may borrow under
its facility and could transfer any of its borrowings to affiliated companies.
OE and MYR had $19 million and $46 million, respectively, of unused bank
facilities as of December 31, 2002. An additional source of ongoing cash for
FirstEnergy, as a holding company, is cash dividends from its subsidiaries. In
2002, the holding company received $447 million of cash dividends on common
stock from its subsidiaries.
Based on their present plans, the Companies could provide for their
cash requirements in 2003 from the following sources: funds to be received from
operations; available cash and temporary cash investments as of December 31,
2002 (Company's nonutility subsidiaries-$93 million, OE-$20 million, Penn-$1
million, CEI-$30 million, TE-$21 million, JCP&L-$5 million, Met-Ed-$16 million
and Penelec-$10 million); the issuance of long-term debt (for refunding
purposes); and funds available under revolving credit arrangements.
10
The extent and type of future financings will depend on the need for
external funds as well as market conditions, the maintenance of an appropriate
capital structure and the ability of the Companies to comply with coverage
requirements in order to issue first mortgage bonds and preferred stock. The
Companies will continue to monitor financial market conditions and, where
appropriate, may take advantage of economic opportunities to refund debt and
preferred stock to the extent that their financial resources permit.
The coverage requirements contained in the first mortgage indentures
under which the Companies issue first mortgage bonds provide that, except for
certain refunding purposes, the Companies may not issue first mortgage bonds
unless applicable net earnings (before income taxes), calculated as provided in
the indentures, for any period of twelve consecutive months within the fifteen
calendar months preceding the month in which such additional bonds are issued,
are at least twice annual interest requirements on outstanding first mortgage
bonds, including those being issued. Under OE's first mortgage indenture, the
availability of property additions is more restrictive than the earnings test at
the present time and would limit the amount of first mortgage bonds issuable
against property additions to $172 million. OE is currently able to issue $1.195
billion principal amount of first mortgage bonds against previously retired
bonds without the need to meet the above restrictions. Under Penn's first
mortgage indenture, other requirements also apply and are more restrictive than
the earnings test at the present time. Penn is currently able to issue $323
million principal amount of first mortgage bonds, with up to $150 million of
such amount issuable against property additions; the remainder could be issued
against previously retired bonds. CEI and TE can issue $379 million and $144
million principal amount of first mortgage bonds against a combination of
previously retired bonds and property additions, respectively. TE cannot
currently issue first mortgage bonds. JCP&L, Met-Ed and Penelec are able to
issue $393 million, $74 million and $7 million principal amount, respectively,
of first mortgage bonds against previously retired bonds.
OE's, Penn's, TE's and JCP&L's respective articles of incorporation
prohibit the sale of preferred stock unless applicable gross income, calculated
as provided in the articles of incorporation, is equal to at least 1-1/2 times
the aggregate of the annual interest requirements on indebtedness and annual
dividend requirements on preferred stock outstanding immediately thereafter.
Based upon earnings for 2002, an assumed dividend rate of 9%, and no additional
indebtedness, OE, Penn and JCP&L would be permitted, under the earnings coverage
test contained in their respective charters, to issue at least $2.8 billion,
$251 million and $1.2 billion of preferred stock, respectively; TE cannot
currently issue preferred stock. There are no restrictions on the ability of
CEI, Met-Ed and Penelec to issue preferred stock.
To the extent that coverage requirements or market conditions restrict
the Companies' abilities to issue desired amounts of first mortgage bonds or
preferred stock, the Companies may seek other methods of financing. Such
financings could include the sale of preferred and/or preference stock or of
such other types of securities as might be authorized by applicable regulatory
authorities which would not otherwise be sold and could result in annual
interest charges and/or dividend requirements in excess of those that would
otherwise be incurred.
Met-Ed Capital Trust and Penelec Capital Trust
In 1999, Met-Ed Capital Trust, a wholly owned subsidiary of Met-Ed,
issued $100 million of trust preferred securities (Met-Ed Trust Preferred
Securities) at 7.35%, due 2039. The sole assets of Met-Ed Capital Trust are the
7.35% Cumulative Preferred Securities of Met-Ed Capital II, L.P. (Met-Ed
Partnership Preferred Securities) and its only revenues are the quarterly cash
distributions it receives on the Met-Ed Partnership Preferred Securities. Each
Met-Ed Trust Preferred Security represents a Met-Ed Partnership Preferred
Security. Met-Ed Capital II, L.P. is a wholly-owned subsidiary of Met-Ed and the
sponsor of Met-Ed Capital Trust. The sole assets of Met-Ed Capital II, L.P. are
Met-Ed's 7.35% Subordinated Debentures, Series A, due 2039, which have an
aggregate principal amount of $103.1 million. Distributions were made on the
Trust Preferred Securities during 2002 in the aggregate amount of $7,350,000.
Expenses of Met-Ed Trust for 2002 were approximately $13,000, all of which were
paid by Met-Ed Preferred Capital II, Inc., the general partner of Met-Ed Capital
II, L.P. The Trust Preferred Securities are issued in book-entry form only so
that there is only one holder of record. Met-Ed has fully and unconditionally
guaranteed the Met-Ed Partnership Preferred Securities, and, therefore, the
Met-Ed Trust Preferred Securities.
In 1999, Penelec Capital Trust, a wholly owned subsidiary of Penelec,
issued $100 million of trust preferred securities (Penelec Trust Preferred
Securities) at 7.34%, due 2039. The sole assets of Penelec Capital Trust are the
7.34% Cumulative Preferred Securities of Penelec Capital II, L.P. (Penelec
Partnership Preferred Securities) and its only revenues are the quarterly cash
distributions it receives on the Penelec Partnership Preferred Securities. Each
Penelec Trust Preferred Security represents a Penelec Partnership Preferred
Security. Penelec Capital II, L.P. is a wholly-owned subsidiary of Penelec and
the sponsor of Penelec Capital Trust. The sole assets of Penelec Capital II,
L.P. are Penelec's 7.34% Subordinated Debentures, Series A, due 2039, which have
an aggregate principal amount of $103.1 million. Distributions were made on the
Trust Preferred Securities during 2002 in the aggregate amount of $7,340,000.
Expenses of Penelec Trust for 2002 were approximately $13,000, all of which were
paid by Penelec Preferred Capital II, Inc., the general partner of Penelec
Capital II, L.P. The Trust Preferred Securities are issued in book-entry form
only so that there is only one holder of record. Penelec has fully and
unconditionally guaranteed the Penelec Partnership Preferred Securities, and,
therefore, the Penelec Trust Preferred Securities.
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NUCLEAR REGULATION
The construction, operation and decommissioning of nuclear generating
units are subject to the regulatory jurisdiction of the Nuclear Regulatory
Commission (NRC) including the issuance by it of construction permits, operating
licenses, and possession only licenses for decommissioning reactors. The NRC's
procedures with respect to the amendment of nuclear reactor operating licenses
afford opportunities for interested parties to request adjudicatory hearings on
health, safety and environmental issues subject to meeting NRC "standing"
requirements. The NRC may require substantial changes in operation or the
installation of additional equipment to meet safety or environmental standards,
subject to the backfit rule requiring the NRC to justify such new requirements
as necessary for the overall protection of public health and safety. The
possibility also exists for modification, denial or revocation of licenses. As a
result of the merger with GPU, FirstEnergy now owns the Three Mile Island Unit 2
(TMI-2) and the Saxton Nuclear Experimental Facility. Both facilities are in
various stages of decommissioning. TMI-2 is in a post-defueling monitored
storage condition, with decommissioning planned in 2014. Saxton is in the final
stages of decommissioning, with license termination scheduled for the end of
2003 and final site restoration scheduled for the first quarter of 2003. Beaver
Valley Unit 1 was placed in commercial operation in 1976, and its operating
license expires in 2016. Davis-Besse was placed in commercial operation in 1977,
and its operating license expires in 2017. Perry Unit 1 and Beaver Valley Unit 2
were placed in commercial operation in 1987, and their operating licenses expire
in 2026 and 2027, respectively.
Davis-Besse, which is operated by FENOC, began its scheduled refueling
outage on February 16, 2002. The plant was originally scheduled to return to
service by the end of March 2002. During the refueling outage, visual and
ultrasonic testings were conducted on all 69 of the Control Rod Drive Mechanism
penetration nozzles. This testing was performed to check for the kind of
circular or circumferential cracking in these nozzles that had been found at
some other plants similar in design and vintage to Davis-Besse. Based on the
inspection and test results, five nozzles were scheduled for repair during the
refueling outage.
As repair work began on one of the nozzles, FENOC found corrosion in
the reactor vessel head near some of the penetration holes, created by boric
acid deposits from leaks in the nozzles. As a result, the NRC issued a
confirmatory action letter stating that restart of the plant would be subject to
prior NRC approval, and it established an Inspection Manual Chapter 0350
Oversight Panel to ensure close NRC oversight of Davis-Besse's corrective
actions.
In response to the reactor vessel head degradation, FENOC initiated a
number of root cause analyses and other assessments, and established a Return to
Service Plan to correct the causes and ensure a safe and reliable return to
service. The Return to Service Plan includes actions to: replace the reactor
vessel head, inspect and correct other components in the containment that may
have been affected by boric acid, review important systems and programs to
ensure their readiness for restart, and improve management and human
performance. FENOC has completed many of the actions under the Return to Service
Plan and is currently implementing corrective actions and performing tests to
ensure the readiness of the plant to restart.
FENOC anticipates that Davis-Besse will be ready for restart in the
first half of the summer of 2003. However, the NRC must authorize restart of the
plant following its formal inspection process before the unit can be returned to
service. In 2002, FENOC spent approximately $115 million in additional
nuclear-related operation and maintenance costs, approximately $120 million in
replacement power costs and approximately $63 million in capital expenditures
related to the reactor head and restart. For 2003, FENOC expects to spend
approximately $50 million in additional nuclear-related operation and
maintenance costs and approximately $12-18 million in replacement power costs
per month. These costs could increase if the length of the outage increases.
The NRC has promulgated and continues to promulgate orders and
regulations related to the safe operation of nuclear power plants and standards
for decommissioning clean-up and final license termination. The Companies cannot
predict what additional orders and regulations (including post-September 11,
2001 security enhancements) may be promulgated, design changes required or the
effect that any such regulations or design changes or additional clean-up
standards for final site release, or the consideration thereof, may have upon
their nuclear plants. Although the Companies have no reason to anticipate an
accident at any of their nuclear plants, if such an accident did happen, it
could have a material but currently undeterminable adverse effect on
FirstEnergy's consolidated financial position. In addition, such an accident at
any operating nuclear plant, whether or not owned by the Companies, could result
in regulations or requirements that could affect the operation, licensing, or
decommissioning of plants that the Companies do own with a consequent but
currently undeterminable adverse impact, and could affect the Companies'
abilities to raise funds in the capital markets.
NUCLEAR INSURANCE
The Price-Anderson Act limits the public liability which can be
assessed with respect to a nuclear power plant to $9.5 billion (assuming 105
units licensed to operate) for a single nuclear incident, which amount is
covered by: (i) private insurance amounting to $300 million; and (ii) $9.2
billion provided by an industry retrospective rating plan required by the NRC
pursuant thereto. Under such retrospective rating plan, in the event of a
nuclear incident at any unit in the United States resulting in losses in excess
of private insurance, up to $88.1 million (but not more than $10 million
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per unit per year in the event of more than one incident) must be contributed
for each nuclear unit licensed to operate in the country by the licensees
thereof to cover liabilities arising out of the incident. Based on their present
nuclear ownership and leasehold interests, the Companies' maximum potential
assessment under these provisions would be $352.4 million (OE-$94.2 million,
Penn-$74.0 million, CEI-$106.3 million and TE-$77.9 million) per incident but
not more than $40.0 million (OE-$10.7 million, Penn-$8.4 million, CEI-$12.1
million and TE-$8.8 million) in any one year for each incident.
In addition to the public liability insurance provided pursuant to the
Price-Anderson Act, the Companies have also obtained insurance coverage in
limited amounts for economic loss and property damage arising out of nuclear
incidents. The Companies are members of Nuclear Electric Insurance Limited
(NEIL) which provides coverage (NEIL I) for the extra expense of replacement
power incurred due to prolonged accidental outages of nuclear units. Under NEIL
I, the Companies have policies, renewable yearly, corresponding to their
respective nuclear interests, which provide an aggregate indemnity of up to
approximately $1.182 billion (OE-$315 million, Penn-$222 million, CEI-$382
million and TE-$263 million) for replacement power costs incurred during an
outage after an initial 12-week waiting period. Members of NEIL I pay annual
premiums and are subject to assessments if losses exceed the accumulated funds
available to the insurer. The Companies' present maximum aggregate assessment
for incidents at any covered nuclear facility occurring during a policy year
would be approximately $11.1 million (OE-$3.1 million, Penn-$2.2 million,
CEI-$3.4 million and TE-$2.4 million).
The Companies are insured as to their respective nuclear interests
under property damage insurance provided by NEIL to the operating company for
each plant. Under these arrangements, $2.75 billion of coverage for
decontamination costs, decommissioning costs, debris removal and repair and/or
replacement of property is provided. The Companies pay annual premiums for this
coverage and are liable for retrospective assessments of up to approximately
$57.3 million (OE-$15.5 million, Penn-$10.9 million, CEI-$17.9 million, TE-$12.2
million, JCP&L-$0.2 million, Met-Ed-$0.4 million and Penelec-$0.2 million)
during a policy year.
The Companies intend to maintain insurance against nuclear risks as
described above as long as it is available. To the extent that replacement
power, property damage, decontamination, decommissioning, repair and replacement
costs and other such costs arising from a nuclear incident at any of the
Companies' plants exceed the policy limits of the insurance in effect with
respect to that plant, to the extent a nuclear incident is determined not to be
covered by the Companies' insurance policies, or to the extent such insurance
becomes unavailable in the future, the Companies would remain at risk for such
costs.
The NRC requires nuclear power plant licensees to obtain minimum
property insurance coverage of $1.06 billion or the amount generally available
from private sources, whichever is less. The proceeds of this insurance are
required to be used first to ensure that the licensed reactor is in a safe and
stable condition and can be maintained in that condition so as to prevent any
significant risk to the public health and safety. Within 30 days of
stabilization, the licensee is required to prepare and submit to the NRC a
cleanup plan for approval. The plan is required to identify all cleanup
operations necessary to decontaminate the reactor sufficiently to permit the
resumption of operations or to commence decommissioning. Any property insurance
proceeds not already expended to place the reactor in a safe and stable
condition must be used first to complete those decontamination operations that
are ordered by the NRC. The Companies are unable to predict what effect these
requirements may have on the availability of insurance proceeds to the Companies
for the Companies' bondholders.
ENVIRONMENTAL MATTERS
Various federal, state and local authorities regulate the Companies
with regard to air and water quality and other environmental matters.
FirstEnergy estimates additional capital expenditures for environmental
compliance of approximately $159 million, which is included in the construction
forecast provided under "Capital Requirements" for 2003 through 2007.
Air Regulation
Under the provisions of the Clean Air Act of 1970, the States of Ohio
and New Jersey and the Commonwealth of Pennsylvania have adopted ambient air
quality standards, and related emission limits, including limits for sulfur
dioxide (SO(2)) and particulates. In addition, the U.S. Environmental Protection
Agency (EPA) promulgated an SO(2) regulatory plan for Ohio which became
effective for OE's, CEI's and TE's plants in 1977. Generating plants to be
constructed in the future and some future modifications of existing facilities
will be covered not only by the applicable state standards but also by EPA
emission performance standards for new sources. In Ohio, New Jersey and
Pennsylvania the construction or certain modifications of emission sources
requires approval from appropriate environmental authorities, and the facilities
involved may not be operated unless a permit or variance to do so has been
issued by those same authorities.
The Companies are required to meet federally approved SO(2)
regulations. Violations of such regulations can result in shutdown of the
generating unit involved and/or civil or criminal penalties of up to $31,500 for
each day the unit is in violation. The EPA has an interim enforcement policy for
SO(2) regulations in Ohio that allows for compliance based
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on a 30-day averaging period. The Companies cannot predict what action the EPA
may take in the future with respect to the interim enforcement policy.
The Companies believe they are in compliance with the current SO(2) and
nitrogen oxide (NO(x)) reduction requirements under the Clean Air Act Amendments
of 1990. SO(2) reductions are being achieved by burning lower-sulfur fuel,
generating more electricity from lower-emitting plants, and/or using emission
allowances. NO(x) reductions are being achieved through combustion controls and
the generation of more electricity at lower-emitting plants. In September 1998,
the EPA finalized regulations requiring additional NO(x) reductions from the
Companies' Ohio, New Jersey and Pennsylvania facilities. The EPA's NO(x)
Transport Rule imposes uniform reductions of NOx emissions (an approximate 85%
reduction in utility plant NO(x) emissions from projected 2007 emissions) across
a region of nineteen states and the District of Columbia, including New Jersey,
Ohio and Pennsylvania, based on a conclusion that such NO(x) emissions are
contributing significantly to ozone pollution in the eastern United States.
State Implementation Plans (SIP) must comply by May 31, 2004 with individual
state NOx budgets established by the EPA. Pennsylvania submitted a SIP that
requires compliance with the NOx budgets at the Companies' Pennsylvania
facilities by May 1, 2003 and Ohio submitted a SIP that requires compliance with
the NO(x) budgets at the Companies' Ohio facilities by May 31, 2004. The
Companies continue to evaluate their compliance plans and other compliance
options.
In July 1997, the EPA promulgated changes in the National Ambient Air
Quality Standard (NAAQS) for ozone emissions and proposed a new NAAQS for
previously unregulated ultra-fine particulate matter. In May 1999, the U.S.
Court of Appeals found constitutional and other defects in the new NAAQS rules.
In February 2001, the U.S. Supreme Court upheld the new NAAQS rules regulating
ultra-fine particulates but found defects in the new NAAQS rules for ozone and
decided that the EPA must revise those rules. The future cost of compliance with
these regulations may be substantial and will depend if and how they are
ultimately implemented by the states in which the Companies operate affected
facilities.
In 1999 and 2000, the EPA issued Notices of Violation (NOV) or a
Compliance Order to nine utilities covering 44 power plants, including the W. H.
Sammis Plant. In addition, the U.S. Department of Justice filed eight civil
complaints against various investor-owned utilities, which included a complaint
against OE and Penn in the U.S. District Court for the Southern District of
Ohio, for which hearings began on February 3, 2003. The NOV and complaint allege
violations of the Clean Air Act based on operation and maintenance of the Sammis
Plant dating back to 1984. The complaint requests permanent injunctive relief to
require the installation of "best available control technology" and civil
penalties of up to $27,500 per day of violation. Although unable to predict the
outcome of these proceedings, FirstEnergy believes the Sammis Plant is in full
compliance with the Clean Air Act and the NOV and complaint are without merit.
Penalties could be imposed if the Sammis Plant continues to operate without
correcting the alleged violations and a court determines that the allegations
are valid. The Sammis Plant continues to operate while these proceedings are
pending.
In December 2000, the EPA announced it would proceed with the
development of regulations regarding hazardous air pollutants from electric
power plants. The EPA identified mercury as the hazardous air pollutant of
greatest concern. The EPA established a schedule to propose regulations by
December 2003 and issue final regulations by December 2004. The future cost of
compliance with these regulations may be substantial.
Water Regulation
Various water quality regulations, the majority of which are the result
of the federal Clean Water Act and its amendments, apply to the Companies'
plants. In addition, Ohio, New Jersey and Pennsylvania have water quality
standards applicable to the Companies' operations. As provided in the Clean
Water Act, authority to grant federal National Pollutant Discharge Elimination
System water discharge permits can be assumed by a state. Ohio, New Jersey and
Pennsylvania have assumed such authority.
Waste Disposal
As a result of the Resource Conservation and Recovery Act of 1976, as
amended, and the Toxic Substances Control Act of 1976, federal and state
hazardous waste regulations have been promulgated. Certain fossil-fuel
combustion waste products, such as coal ash, were exempted from hazardous waste
disposal requirements pending the EPA's evaluation of the need for future
regulation. The EPA has issued its final regulatory determination that
regulation of coal ash as a hazardous waste is unnecessary. In April 2000, the
EPA announced that it will develop national standards regulating disposal of
coal ash under its authority to regulate nonhazardous waste.
The Companies have been named as "potentially responsible parties"
(PRPs) at waste disposal sites which may require cleanup under the Comprehensive
Environmental Response, Compensation and Liability Act of 1980. Allegations of
disposal of hazardous substances at historical sites and the liability involved
are often unsubstantiated and subject to dispute; however, federal law provides
that all PRPs for a particular site be held liable on a joint and several basis.
Therefore, potential environmental liabilities have been recognized on the
Consolidated Balance Sheet as of December 31, 2002, based on estimates of the
total costs of cleanup, the Companies' proportionate responsibility for such
costs and the financial ability of other nonaffiliated entities to pay. In
addition, JCP&L has accrued liabilities for
14
environmental remediation of former manufactured gas plants in New Jersey; those
costs are being recovered by JCP&L through its SBC. The Companies have total
accrued liabilities aggregating approximately $54.3 million as of December 31,
2002.
In 1980, Congress passed the Low-Level Radioactive Waste Policy Act
which provides that the disposal of low-level radioactive waste is the
responsibility of the state where such waste is generated. The Act encourages
states to form compacts among themselves to develop regional disposal
facilities. Failure by a state or compact to begin implementation of a program
could result in access denial to the two facilities currently accepting
low-level radioactive waste. Ohio is part of the Midwest Compact and has
responsibility for siting and constructing a disposal facility. On June 26,
1997, the Midwest Compact Commission (Compact) voted to cease all siting
activities in the host state of Ohio and to dismantle the Ohio Low-Level
Radioactive Waste Facility Development Authority, the statutory agency charged
with siting and constructing the low-level radioactive waste disposal facility.
While the Compact remains intact, it has no plans to site or construct a
low-level radioactive waste disposal facility in the Midwest. The Companies
continue to ship low-level radioactive waste from their nuclear facilities to
the Barnwell, South Carolina waste disposal facility.
Summary
Environmental controls are still developing and require, in many
instances, balancing the needs for additional quantities of energy in future
years and the need to protect the environment. As a result, the Companies cannot
now estimate the precise effect of existing and potential regulations and
legislation upon any of their existing and proposed facilities and operations or
upon their ability to issue additional first mortgage bonds under their
respective mortgages. These mortgages contain covenants by the Companies to
observe and conform to all valid governmental requirements at the time
applicable unless in course of contest, and provisions which, in effect, prevent
the issuance of additional bonds if there is a completed default under the
mortgage. The provisions of each of the mortgages, in effect, also require, in
the opinion of counsel for the respective Companies, that certification of
property additions as the basis for the issuance of bonds or other action under
the mortgages be accompanied by an opinion of counsel that the company
certifying such property additions has all governmental permissions at the time
necessary for its then current ownership and operation of such property
additions. The Companies intend to contest any requirements they deem
unreasonable or impossible for compliance or otherwise contrary to the public
interest. Developments in these and other areas of regulation may require the
Companies to modify, supplement or replace equipment and facilities, and may
delay or impede the construction and operation of new facilities, at costs which
could be substantial.
The effects of compliance on the Companies with regard to environmental
matters could have a material adverse effect on FirstEnergy's earnings and
competitive position. These environmental regulations affect FirstEnergy's
earnings and competitive position to the extent it competes with companies that
are not subject to such regulations and therefore do not bear the risk of costs
associated with compliance, or failure to comply, with such regulations.
FirstEnergy believes it is in material compliance with existing regulations but
is unable to predict whether environmental regulations will change and what, if
any, the effects of such change would be.
FUEL SUPPLY
The Companies' sources of generation during 2002 were:
FOSSIL NUCLEAR
------ -------
OE.................... 74.5% 25.5%
Penn.................. 34.6% 65.4%
CEI................... 67.3% 32.7%
TE.................... 61.8% 38.2%
Total FirstEnergy..... 65.6% 34.4%
Generation from JCP&L's and Met-Ed's hydro and combustion turbine
generation facilities was minimal in 2002.
FirstEnergy currently has long-term coal contracts to provide
approximately 12,400,000 tons for the year 2003. The contracts are shared among
the Companies based on various economic considerations. This contract coal is
produced primarily from mines located in Pennsylvania, Kentucky and West
Virginia. The contracts expire at various times through December 31, 2019.
The Companies estimate their 2003 coal requirements to be approximately
18,860,000 tons (OE - 7,250,000, Penn - 6,000,000, CEI - 4,170,000, and TE -
1,440,000) to be met from the long-term contracts discussed above and spot
market purchases. See "Environmental Matters" for factors pertaining to meeting
environmental regulations affecting coal-fired generating units.
FirstEnergy has contracts for uranium material and conversion services
through 2006. The enrichment services are contracted for the majority of the
enrichment requirements for nuclear fuel through 2006. Fabrication
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services for fuel assemblies are contracted for the next four reloads for Beaver
Valley Unit 1, the next three reloads for Beaver Valley Unit 2 (through
approximately 2007 and 2006, respectively), the next two reloads for Davis-Besse
(through approximately 2007) and through the operating license period for Perry
(through approximately 2026). In addition to the existing commitments,
FirstEnergy intends to make additional arrangements for the supply of uranium
and for the subsequent conversion, enrichment, fabrication, and waste disposal
services.
On-site spent fuel storage facilities are expected to be adequate for
Perry through 2011; facilities at Beaver Valley Units 1 and 2 are expected to be
adequate through 2018 and 2009, respectively. With the plant modifications
completed in 2002, Davis-Besse has adequate storage through the remainder of its
operating license period. After current on-site storage capacity is exhausted,
additional storage capacity will have to be obtained either through plant
modifications, interim off-site disposal, or permanent waste disposal
facilities. The Federal Nuclear Waste Policy Act of 1982 provides for the
construction of facilities for the permanent disposal of high-level nuclear
wastes, including spent fuel from nuclear power plants operated by electric
utilities; however, the selection of a suitable site is embroiled in the
political process. FirstEnergy has contracts with the U.S. Department of Energy
(DOE) for the disposal of spent fuel for Beaver Valley, Davis-Besse and Perry.
On February 15, 2002, President Bush approved the DOE's recommendation of Yucca
Mountain for underground disposal of spent nuclear fuel from nuclear power
plants and high level waste from U.S. defense programs. The recommendation by
President Bush enables the process to proceed to the licensing phase. Based on
the DOE schedule published in the July 1999 Draft Environmental Impact
Statement, the Yucca Mountain Repository is currently projected to start
receiving spent fuel in 2010. FirstEnergy intends to make additional
arrangements for storage capacity as a contingency for further delays with the
DOE acceptance of spent fuel for disposal past 2010.
SYSTEM CAPACITY AND RESERVES
The 2002 net maximum hourly demand for each of the Companies was:
OE-6,757 MW (including an additional 387 MW of firm power sales under a contract
which extends through 2005) on August 1, 2002; Penn-969 MW (including an
additional 63 MW of firm power sales under a contract which extends through
2005) on July 29, 2002; CEI-4,561 MW on August 1, 2002; TE-2,104 MW on July 3,
2002; JCP&L-5,802 MW on August 2, 2002; Met-Ed-2,616 MW on August 14, 2002; and
Penelec-2,693 MW on July 29, 2002. JCP&L's load was auctioned off in the New
Jersey BGS Auction, transferring the full 5,100 MW load obligation to other
parties for the period August 1, 2002 to July 31, 2003. FES participated in the
auction and won a segment of that load.
Based on existing capacity plans, ongoing arrangements for firm
purchase contracts, and anticipated term power sales and purchases, FirstEnergy
has sufficient supply resources to meet load obligations. The current
FirstEnergy capacity portfolio contains 13,387 MW of owned generation and
approximately 1,600 MW of long-term purchases from non-utility generators.
Any remaining load obligations will be met through a mix of multi-year
forward purchases, short-term forward purchases (less than one year) and spot
market purchases.
REGIONAL RELIABILITY
The Companies participate with 24 other electric companies operating in
nine states in ECAR, which was organized for the purpose of furthering the
reliability of bulk power supply in the area through coordination of the
planning and operation by the ECAR members of their bulk power supply
facilities. The ECAR members have established principles and procedures
regarding matters affecting the reliability of the bulk power supply within the
ECAR region. Procedures have been adopted regarding: i) the evaluation and
simulated testing of systems' performance; ii) the establishment of minimum
levels of daily operating reserves; iii) the development of a program regarding
emergency procedures during conditions of declining system frequency; and iv)
the basis for uniform rating of generating equipment.
Following the FirstEnergy/GPU merger the transmission facilities of
JCP&L, Met-Ed and Penelec continue to be operated by PJM. PJM is the
organization responsible for the operation and control of the bulk electric
power system throughout major portions of five Mid-Atlantic states and the
District of Columbia. PJM is dedicated to meeting the reliability criteria and
standards of the North American Electric Reliability Council and the
Mid-Atlantic Area Council.
COMPETITION
The Companies traditionally competed with other utilities for
intersystem bulk power sales and for sales to municipalities and cooperatives.
The Companies compete with suppliers of natural gas and other forms of energy in
connection with their industrial and commercial sales and in the home climate
control market, both with respect to new customers and conversions, and with all
other suppliers of electricity. To date, there has been no substantial
cogeneration by the Companies' customers.
As a result of the actions taken by state legislative bodies over the
last few years, major changes in the electric utility business are occurring in
parts of the United States, including Ohio, New Jersey and Pennsylvania where
16
FirstEnergy's utility subsidiaries operate. These changes have resulted in
fundamental alterations in the way traditional integrated utilities and holding
company systems, like FirstEnergy, conduct their business. In accordance with
the Ohio electric utility restructuring law under which Ohio electric customers
could begin choosing their electric generation suppliers starting in January
2001, FirstEnergy has further aligned its business units to accommodate its
retail strategy and participate in the competitive electricity marketplace in
Ohio. The organizational changes deal with the unbundling of electric utility
services and new ways of conducting business.
Sales of electricity in deregulated markets are diversifying
FirstEnergy's revenue sources through its competitive subsidiaries in areas
outside of the Companies' franchise areas. This strategy has positioned
FirstEnergy to compete in the northeast quadrant of the United States - the
region targeted by FirstEnergy for growth. FirstEnergy's competitive
subsidiaries are actively participating in deregulated energy markets in Ohio,
Pennsylvania, New Jersey, Delaware, Maryland and Michigan. Currently, FES is
providing electric generation service to customers within those states. As
additional states within the northeast region of the United States become
deregulated, FES is preparing to enter these markets.
Competition in Ohio's electric generation began on January 1, 2001.
FirstEnergy moved the operation of the generation portion of its business to its
competitive business unit as reflected in its approved Ohio transition plan. The
Companies continue to provide generation services to regulated franchise
customers who have not chosen an alternative, competitive generation supplier,
except in New Jersey where JCP&L's obligation to provide BGS has been removed
through a transitional mechanism of auctioning the obligation (see "NJBPU Rate
Matters"). In September 2002, Met-Ed and Penelec assigned their PLR
responsibility to FES through a wholesale power sale agreement. Under the
agreement terms, FES assumes the supply obligation and the energy supply profit
and loss risk for the portion of power supply requirements not self-supplied by
Met-Ed and Penelec. The agreement is automatically extended on an annual basis
unless any party elects to cancel the agreement by November 1 of the preceding
year (see "PPUC Rate Matters" for further discussion). The Ohio Companies and
Penn obtain their generation through power supply agreements with FES. In
addition to electric generation, FES is also competing in deregulated natural
gas markets as well as offering other energy-related products and services.
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RESEARCH AND DEVELOPMENT
The Companies participate in funding the Electric Power Research
Institute (EPRI), which was formed for the purpose of expanding electric
research and development under the voluntary sponsorship of the nation's
electric utility industry - public, private and cooperative. Its goal is to
mutually benefit utilities and their customers by promoting the development of
new and improved technologies to help the utility industry meet present and
future electric energy needs in environmentally and economically acceptable
ways. EPRI conducts research on all aspects of electric power production and
use, including fuels, generation, delivery, energy management and conservation,
environmental effects and energy analysis. The major portion of EPRI research
and development projects is directed toward practical solutions and their
applications to problems currently facing the electric utility industry. In
2002, approximately 69% of the Companies' research and development expenditures
were related to EPRI.
EXECUTIVE OFFICERS
The executive officers are elected at the annual organization
meeting of the Board of Directors, held immediately after the annual meeting of
stockholders, and hold office until the next such organization meeting, unless
the Board of Directors shall otherwise determine, or unless a resignation is
submitted.
POSITION HELD DURING
NAME AGE PAST FIVE YEARS DATES
----------------- --- -------------------------------------------------------------------- --------------------
H. P. Burg 56 Chairman of the Board and Chief Executive Officer 2002-present
Vice Chairman of the Board and Chief Executive Officer 2001-2002
Chairman of the Board and Chief Executive Officer 2000-2001
President and Chief Executive Officer 1999-2000
President and Chief Operating Officer 1998-1999
President and Chief Financial Officer *-1998
A. J. Alexander 51 President and Chief Operating Officer 2001-present
President 2000-2001
Executive Vice President and General Counsel *-2000
A. R. Garfield 64 President - FirstEnergy Solutions 2001-present
Senior Vice President - Supply and Sales 2000-2001
Vice President - Business Development *-2000
R. F. Saunders 59 President and Chief Nuclear Officer - FENOC 2000-present
Vice President, Nuclear Site Operations - Pennsylvania Power & Light 1998-2000
Vice President, Nuclear Engineering - Virginia Power Company *-1998
E. T. Carey 60 Senior Vice President 2001-present
Vice President - Distribution *-2001
K. J. Keough 43 Senior Vice President 2001-present
Vice President - Business Planning & Ventures 1999-2001
Partner - McKinsey & Company *-1999
R. H. Marsh 52 Senior Vice President and Chief Financial Officer 2001-present
Vice President and Chief Financial Officer 1998-2001
Vice President - Finance *-1998
C. B. Snyder 57 Senior Vice President 2001-present
Executive Vice President - Corporate Affairs - GPU 1998-2001
Senior Vice President - Corporate Affairs - GPU *-1998
L. L. Vespoli 43 Senior Vice President and General Counsel 2001-present
Vice President and General Counsel 2000-2001
Associate General Counsel *-2000
H. L. Wagner 50 Vice President, Controller and Chief Accounting Officer 2001-present
Controller *-2001
Mrs. Vespoli and Messrs. Burg, Carey, Marsh and Wagner are the executive
officers, as noted above, of OE, Penn, CEI, TE, Met-Ed and Penelec. Mrs. Vespoli
and Messrs. Carey, Marsh and Wagner are the executive officers of JCP&L.
* Indicates position held at least since January 1, 1998.
FIRSTENERGY WEBSITE
Each of the registrant's annual report on Form 10-K, quarterly reports on Form
10-K, current reports on Form 8-K, and amendments to those reports filed with or
furnished to the SEC pursuant to Section 13(a) or 15(d) of the Securities
Exchange Act of 1934 are also made available free of charge on or through
FirstEnergy's internet website at www.firstenergycorp.com. These reports are
posted on the website as soon as reasonably practicable after they are
electronically filed with the SEC.
18
As of January 1, 2003, FirstEnergy's nonutility subsidiaries and the
Companies had a total of 17,560 employees located in the United States as
follows: FirstEnergy - 1,744, OE - 1,368, CEI - 974, TE - 508, Penn - 201, JCP&L
- 39, Met-Ed - 61, ATSI - 29, FES - 2,072, FENOC - 2,850, FSG - 3,317, MARBEL -
32 and GPUS - 4,365 (primarily employees supporting JCP&L, Met-Ed and Penelec).
ITEM 6. SELECTED FINANCIAL DATA
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
The information required for items 6 through 8 is incorporated
herein by reference to Selected Financial Data, Management's Discussion and
Analysis of Results of Operations and Financial Condition and Financial
Statements included on the pages shown in the following table in FirstEnergy's
2002 Annual Report to Stockholders, as revised (Exhibit 13 below).
ITEM 6 ITEM 7 ITEM 8
------ ------ ------
FirstEnergy.............. 4 5-31 32-74
OE....................... 1 2-14 15-36
CEI...................... 1 2-15 16-40
TE....................... 1 2-15 16-40
ITEM 14. CONTROLS AND PROCEDURES
(A) EVALUATION OF DISCLOSURE CONTROLS AND PROCEDURES
The applicable registrant's chief executive officer and chief
financial officer have reviewed and evaluated the registrant's disclosure
controls and procedures, as defined in the Securities Exchange Act of 1934 Rules
13a-14(c) and 15d-14(c), as of a date within 90 days prior to the filing date of
this report (Evaluation Date). Based on that evaluation those officers have
concluded that the registrant's disclosure controls and procedures are effective
and were designed to bring to their attention, during the period in which this
annual report was being prepared, material information relating to the
registrant and its consolidated subsidiaries by others within those entities.
(B) CHANGES IN INTERNAL CONTROLS
Effective June 1, 2003, the registrants implemented a new Enterprise
Resource Planning (ERP) system. While the associated business process changes
transform the internal control structure, management believes adequate controls
have been properly integrated into the reengineered ERP-enabled processes and
that internal controls will be enhanced.
PART IV
ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K
(A) 1. FINANCIAL STATEMENTS
Included in Part II of this report and incorporated herein by
reference to FirstEnergy's 2002 Annual Report to Stockholders, as revised
(Exhibit 13 below), at the pages indicated.
FIRST-
ENERGY OE CEI TE
------ -- --- --
Report of Independent Auditors......................................................... 2 37 37 40
Report of Independent Accountants...................................................... 3 38 -- --
Statements of Income - Three Years Ended December 31, 2002............................. 32 15 16 16
Balance Sheets - December 31, 2002 and 2001............................................ 33 16 17 17
Statements of Capitalization - December 31, 2002 and 2001.............................. 34-37 17-18 18-19 18-19
Statements of Common Stockholders' Equity - Three Years Ended December 31, 2002........ 38 19 20 20
Statements of Preferred Stock - Three Years Ended December 31, 2002.................... 39 19 20 20
Statements of Cash Flows - Three Years Ended December 31, 2002......................... 40 20 21 21
Statements of Taxes - Three Years Ended December 31, 2002.............................. 41 21 22 22
Notes to Financial Statements.......................................................... 42-75 22-36 23-36 23-39
19
3. EXHIBITS - FIRSTENERGY
EXHIBIT
NUMBER
-------
3-1 - Articles of Incorporation constituting FirstEnergy
Corp.'s Articles of Incorporation, dated September 17,
1996. (September 17, 1996 Form 8-K, Exhibit C)
3-1(a) - Amended Articles of Incorporation of FirstEnergy Corp.
(Registration No. 333-21011, Exhibit (3)-1)
3-2 - Regulations of FirstEnergy Corp. (September 17, 1996
Form 8-K, Exhibit D)
3-2(a) - FirstEnergy Corp. Amended Code of Regulations.
(Registration No. 333-21011, Exhibit (3)-2)
4-1 - Rights Agreement (December 1, 1997 Form 8-K, Exhibit
4.1)
4-2 - FirstEnergy Corp. to The Bank of New York, Supplemental
Indenture, dated November 7, 2001. (2001 Form 10-K,
Exhibit 4-2)
10-1 - FirstEnergy Corp. Executive and Director Incentive
Compensation Plan, revised November 15, 1999. (1999 Form
10-K, Exhibit 10-1)
10-2 - Amended FirstEnergy Corp. Deferred Compensation Plan for
Directors, revised November 15, 1999. (1999 Form 10-K,
Exhibit 10-2)
10-3 - Employment, severance and change of control agreement
between FirstEnergy Corp. and executive officers. (1999
Form 10-K, Exhibit 10-3)
10-4 - FirstEnergy Corp. Supplemental Executive Retirement
Plan, amended January 1, 1999. (1999 Form 10-K, Exhibit
10-4)
10-5 - FirstEnergy Corp. Executive Incentive Compensation Plan.
(1999 Form 10-K, Exhibit 10-5)
10-6 - Restricted stock agreement between FirstEnergy Corp. and
A. J. Alexander. (1999 Form 10-K, Exhibit 10-6)
10-7 - FirstEnergy Corp. Executive and Director Incentive
Compensation Plan. (1998 Form 10-K, Exhibit 10-1)
10-8 - Amended FirstEnergy Corp. Deferred Compensation Plan for
Directors, amended February 15, 1999. (1998 Form 10-K,
Exhibit 10-2)
10-9 - Restricted stock agreement between FirstEnergy Corp. and
A. J. Alexander. (2000 Form 10-K, Exhibit 10-9)
10-10 - Restricted stock agreement between FirstEnergy Corp. and
H. P. Burg. (2000 Form 10-K, Exhibit 10-10)
10-11 - Stock option agreement between FirstEnergy Corp. and
officers dated November 22, 2000. (2000 Form 10-K,
Exhibit 10-11)
10-12 - Stock option agreement between FirstEnergy Corp. and
officers dated March 1, 2000. (2000 Form 10-K, Exhibit
10-12)
10-13 - Stock option agreement between FirstEnergy Corp. and
director dated January 1, 2000. (2000 Form 10-K, Exhibit
10-13)
10-14 - Stock option agreement between FirstEnergy Corp. and two
directors dated January 1, 2001. (2000 Form 10-K,
Exhibit 10-14)
20
10-15 - Executive and Director Incentive Compensation Plan dated
May 15, 2001. (2001 Form 10-K, Exhibit 10-15)
10-16 - Amended FirstEnergy Corp. Deferred Compensation Plan for
Directors, revised September 18, 2000. (2001 Form 10-K,
Exhibit 10-16)
10-17 - Stock Option Agreements between FirstEnergy Corp. and
Officers dated May 16, 2001. (2001 Form 10-K, Exhibit
10-17)
10-18 - Restricted Stock Agreements between FirstEnergy Corp.
and Officers dated February 20, 2002. (2001 Form 10-K,
Exhibit 10-18)
10-19 - Stock Option Agreements between FirstEnergy Corp. and
One Director dated January 1, 2002. (2001 Form 10-K,
Exhibit 10-19)
10-20 - FirstEnergy Corp. Executive Deferred Compensation Plan.
(2001 Form 10-K, Exhibit 10-20)
10-21 - Executive Incentive Compensation Plan-Tier 2. (2001 Form
10-K, Exhibit 20-21)
10-22 - Executive Incentive Compensation Plan-Tier 3. (2001 Form
10-K, Exhibit 20-22)
10-23 - Executive Incentive Compensation Plan-Tier 4. (2001 Form
10-K, Exhibit 10-23)
10-24 - Executive Incentive Compensation Plan-Tier 5. (2001 Form
10-K, Exhibit 10-24)
10-25 - Amendment to GPU, Inc. 1990 Stock Plan for Employees of
GPU, Inc. and Subsidiaries, effective April 5, 2001.
(2001 Form 10-K, Exhibit 10-25)
10-26 - Form of Amendment, effective November 7, 2001, to GPU,
Inc. 1990 Stock Plan for Employees of GPU, Inc. and
Subsidiaries, Deferred Remuneration Plan for Outside
Directors of GPU, Inc., and Retirement Plan for Outside
Directors of GPU, Inc. (2001 Form 10-K, Exhibit 10-26)
10-27 - GPU, Inc. Stock Option and Restricted Stock Plan for MYR
Group, Inc. Employees. (2001 Form 10-K, Exhibit 10-27)
10-28 Executive and Director Stock Option Agreement dated June
11, 2002.
10-29 Director Stock Option Agreement.
10-30 Executive and Director Executive Incentive Compensation
Plan, Amendment dated May 21, 2002.
10-31 Directors Deferred Compensation Plan, Revised Nov. 19,
2002.
10-32 Executive Incentive Compensation Plan 2002.
10-33 - GPU, Inc. 1990 Stock Plan for Employees of GPU, Inc. and
Subsidiaries as amended and restated to reflect
amendments through June 3, 1999. (1999 Form 10-K,
Exhibit 10-V, File No. 1-6047, GPU, Inc.)
10-34 - Form of 1998 Stock Option Agreement under the GPU, Inc.
1990 Stock Plan for Employees of GPU, Inc. and
Subsidiaries. (1997 Form 10-K, Exhibit 10-Q, File No.
1-6047, GPU, Inc.)
10-35 - Form of 1999 Stock Option Agreement under the GPU, Inc.
1990 Stock Plan for Employees of GPU, Inc. and
Subsidiaries. (1999 Form 10-K, Exhibit 10-W, File No.
1-6047, GPU, Inc.)
10-36 - Form of 2000 Stock Option Agreement under the GPU, Inc.
1990 Stock Plan for Employees of GPU, Inc. and
Subsidiaries. (2000 Form 10-K, Exhibit 10-W, File No.
1-6047, GPU, Inc.)
10-37 - Deferred Remuneration Plan for Outside Directors of GPU,
Inc. as amended and restated effective August 8, 2000.
(2000 Form 10-K, Exhibit 10-O, File No. 1-6047, GPU,
Inc.)
21
10-38 - Retirement Plan for Outside Directors of GPU, Inc. as
amended and restated as of August 8, 2000. (2000 Form
10-K, Exhibit 10-N, File No. 1-6047, GPU, Inc.)
10-39 - Forms of Estate Enhancement Program Agreements entered
into by certain former GPU directors. (1999 Form 10-K,
Exhibit 10-JJ, File No. 1-6047, GPU, Inc.)
* 12.1 - Consolidated fixed charge ratios.
* 13 - FirstEnergy 2002 Annual Report to Stockholders, as
revised. (Only those portions expressly incorporated by
reference in this Form 10-K/A are to be deemed "filed"
with the SEC.)
21 - List of Subsidiaries of the Registrant at December 31,
2002.
* 23 - Consent of Independent Auditors.
* 31.1 - Certification letter from chief executive officer, as
adopted pursuant to Section 302 of the Sarbanes-Oxley
Act.
* 31.2 - Certification letter from chief financial officer, as
adopted pursuant to Section 302 of the Sarbanes-Oxley
Act.
* 32 - Certification letter from chief executive officer and
chief financial officer, as adopted pursuant to Section
906 of the Sarbanes-Oxley Act.
* Indicates revised exhibits included in this Form 10-K/A in electronic
format. Reference is made to the original 10-K for the other exhibits filed with
it.
3. EXHIBITS - OHIO EDISON
2-1 - Agreement and Plan of Merger, dated as of September 13,
1996, between Ohio Edison Company (OE) and Centerior
Energy Corporation. (September 17, 1996 Form 8-K,
Exhibit 2-1)
3-1 - Amended Articles of Incorporation, Effective June 21,
1994, constituting OE's Articles of Incorporation. (1994
Form 10-K, Exhibit 3-1)
3-2 - Amended and Restated Code of Regulations, amended March
15, 2002. (2001 Form 10-K, Exhibit 3-2)
(B) 4-1 - Indenture dated as of August 1, 1930 between OE and
Bankers Trust Company, (now the Bank of New York), as
Trustee, as amended and supplemented by Supplemental
Indentures:
DATED AS OF FILE REFERENCE EXHIBIT NO.
----------- -------------- -----------
March 3, 1931 2-1725 B1, B-1(a),B-1(b)
November 1, 1935 2-2721 B-4
January 1, 1937 2-3402 B-5
September 1, 1937 Form 8-A B-6
June 13, 1939 2-5462 7(a)-7
August 1, 1974 Form 8-A, August 28, 1974 2(b)
July 1, 1976 Form 8-A, July 28, 1976 2(b)
December 1, 1976 Form 8-A, December 15, 1976 2(b)
June 15, 1977 Form 8-A, June 27, 1977 2(b)
SUPPLEMENTAL INDENTURES:
September 1, 1944 2-61146 2(b)(2)
April 1, 1945 2-61146 2(b)(2)
September 1, 1948 2-61146 2(b)(2)
May 1, 1950 2-61146 2(b)(2)
January 1, 1954 2-61146 2(b)(2)
May 1, 1955 2-61146 2(b)(2)
August 1, 1956 2-61146 2(b)(2)
March 1, 1958 2-61146 2(b)(2)
April 1, 1959 2-61146 2(b)(2)
June 1, 1961 2-61146 2(b)(2)
22
DATED AS OF FILE REFERENCE EXHIBIT NO
----------- -------------- ----------
September 1, 1969 2-34351 2(b)(2)
May 1, 1970 2-37146 2(b)(2)
September 1, 1970 2-38172 2(b)(2)
June 1, 1971 2-40379 2(b)(2)
August 1, 1972 2-44803 2(b)(2)
September 1, 1973 2-48867 2(b)(2)
May 15, 1978 2-66957 2(b)(4)
February 1, 1980 2-66957 2(b)(5)
April 15, 1980 2-66957 2(b)(6)
June 15, 1980 2-68023 (b)(4)(b)(5)
October 1, 1981 2-74059 (4)(d)
October 15, 1981 2-75917 (4)(e)
February 15, 1982 2-75917 (4)(e)
July 1, 1982 2-89360 (4)(d)
March 1, 1983 2-89360 (4)(e)
March 1, 1984 2-89360 (4)(f)
September 15, 1984 2-92918 (4)(d)
September 27, 1984 33-2576 (4)(d)
November 8, 1984 33-2576 (4)(d)
December 1, 1984 33-2576 (4)(d)
December 5, 1984 33-2576 (4)(e)
January 30, 1985 33-2576 (4)(e)
February 25, 1985 33-2576 (4)(e)
July 1, 1985 33-2576 (4)(e)
October 1, 1985 33-2576 (4)(e)
January 15, 1986 33-8791 (4)(d)
May 20, 1986 33-8791 (4)(d)
June 3, 1986 33-8791 (4)(e)
October 1, 1986 33-29827 (4)(d)
August 25, 1989 33-34663 (4)(d)
February 15, 1991 33-39713 (4)(d)
May 1, 1991 33-45751 (4)(d)
May 15, 1991 33-45751 (4)(d)
September 15, 1991 33-45751 (4)(d)
April 1, 1992 33-48931 (4)(d)
June 15, 1992 33-48931 (4)(d)
September 15, 1992 33-48931 (4)(e)
April 1, 1993 33-51139 (4)(d)
June 15, 1993 33-51139 (4)(d)
September 15, 1993 33-51139 (4)(d)
November 15, 1993 1-2578 (4)(2)
April 1, 1995 1-2578 (4)(2)
May 1, 1995 1-2578 (4)(2)
July 1, 1995 1-2578 (4)(2)
June 1, 1997 1-2578 (4)(2)
April 1, 1998 1-2578 (4)(2)
June 1, 1998 1-2578 (4)(2)
September 29, 1999 1-2578 (4)(2)
April 1, 2000 1-2578 (4)(2)(a)
April 1, 2000 1-2578 (4)(2)(b)
June 1, 2001 1-2578
(B) 4-2 - General Mortgage Indenture and Deed of Trust dated as of
January 1, 1998 between OE and the Bank of New York, as
Trustee. (Registration No. 333-05277, Exhibit 4(g))
10-1 - Administration Agreement between the CAPCO Group dated
as of September 14, 1967. (Registration No. 2-43102,
Exhibit 5(c)(2)
10-2 - Amendment No. 1 dated January 4, 1974 to Administration
Agreement between the CAPCO Group dated as of September
14, 1967. (Registration No. 2-68906, Exhibit 5(c)(3))
23
10-3 - Transmission Facilities Agreement between the CAPCO
Group dated as of September 14, 1967. (Registration No.
2-43102, Exhibit 5(c)(3))
10-4 - Amendment No. 1 dated as of January 1, 1993 to
Transmission Facilities Agreement between the CAPCO
Group dated as of September 14, 1967. (1993 Form 10-K,
Exhibit 10-4)
10-5 - Agreement for the Termination or Construction of Certain
Agreements effective September 1, 1980 among the CAPCO
Group. (Registration No. 2-68906, Exhibit 10-4)
10-6 - Amendment dated as of December 23, 1993 to Agreement for
the Termination or Construction of Certain Agreements
effective September 1, 1980 among the CAPCO Group. (1993
Form 10-K, Exhibit 10-6)
10-7 - CAPCO Basic Operating Agreement, as amended September 1,
1980. (Registration No. 2-68906, Exhibit 10-5)
10-8 - Amendment No. 1 dated August 1, 1981, and Amendment No.
2 dated September 1, 1982 to CAPCO Basic Operating
Agreement, as amended September 1, 1980. (September 30,
1981 Form 10-Q, Exhibit 20-1 and 1982 Form 10-K, Exhibit
19-3, respectively)
10-9 - Amendment No. 3 dated July 1, 1984 to CAPCO Basic
Operating Agreement, as amended September 1, 1980. (1985
Form 10-K, Exhibit 10-7)
10-10 - Basic Operating Agreement between the CAPCO Companies as
amended October 1, 1991. (1991 Form 10-K, Exhibit 10-8)
10-11 - Basic Operating Agreement between the CAPCO Companies as
amended January 1, 1993. (1993 Form 10-K, Exhibit 10-11)
10-12 - Memorandum of Agreement effective as of September 1,
1980 among the CAPCO Group. (1982 Form 10-K, Exhibit
19-2)
10-13 - Operating Agreement for Beaver Valley Power Station
Units Nos. 1 and 2 as Amended and Restated September 15,
1987, by and between the CAPCO Companies. (1987 Form
10-K, Exhibit 10-15)
10-14 - Construction Agreement with respect to Perry Plant
between the CAPCO Group dated as of July 22, 1974.
(Registration No. 2-52251 of Toledo Edison Company,
Exhibit 5(yy))
10-15 - Amendment No. 3 dated as of October 31, 1980 to the Bond
Guaranty dated as of October 1, 1973, as amended, with
respect to the CAPCO Group. (Registration No. 2-68906 of
Pennsylvania Power Company, Exhibit 10-16)
10-16 - Amendment No. 4 dated as of July 1, 1985 to the Bond
Guaranty dated as October 1, 1973, as amended, by the
CAPCO Companies to National City Bank as Bond Trustee.
(1985 Form 10-K, Exhibit 10-30)
10-17 - Amendment No. 5 dated as of May 1, 1986, to the Bond
Guaranty by the CAPCO Companies to National City Bank as
Bond Trustee. (1986 Form 10-K, Exhibit 10-33)
10-18 - Amendment No. 6A dated as of December 1, 1991, to the
Bond Guaranty dated as of October 1, 1973, by The
Cleveland Electric Illuminating Company, Duquesne Light
Company, Ohio Edison Company, Pennsylvania Power
Company, The Toledo Edison Company to National City
Bank, as Bond Trustee. (1991 Form 10-K, Exhibit 10-33)
10-19 - Amendment No. 6B dated as of December 30, 1991, to the
Bond Guaranty dated as of October 1, 1973 by The
Cleveland Electric Illuminating Company, Duquesne Light
Company, Ohio Edison Company, Pennsylvania Power
Company, The Toledo Edison Company to National City
Bank, as Bond Trustee. (1991 Form 10-K, Exhibit 10-34)
24
10-20 - Bond Guaranty dated as of December 1, 1991, by The
Cleveland Electric Illuminating Company, Duquesne Light
Company, Ohio Edison Company, Pennsylvania Power
Company, The Toledo Edison Company to National City
Bank, as Bond Trustee. (1991 Form 10-K, Exhibit 10-35)
10-21 - Memorandum of Understanding dated March 31, 1985 among
the CAPCO Companies. (1985 Form 10-K, Exhibit 10-35)
(C) 10-22 - Ohio Edison System Executive Supplemental Life Insurance
Plan. (1995 Form 10-K, Exhibit 10-44)
(C) 10-23 - Ohio Edison System Executive Incentive Compensation
Plan. (1995 Form 10-K, Exhibit 10-45.)
(C) 10-24 - Ohio Edison System Restated and Amended Executive
Deferred Compensation Plan. (1995 Form 10-K, Exhibit
10-46.)
(C) 10-25 - Ohio Edison System Restated and Amended Supplemental
Executive Retirement Plan. (1995 Form 10-K, Exhibit
10-47.)
(C) 10-26 - Severance pay agreement between Ohio Edison Company and
W. R. Holland. (1995 Form 10-K, Exhibit 10-48.)
(C) 10-27 - Severance pay agreement between Ohio Edison Company and
H. P. Burg. (1995 Form 10-K, Exhibit 10-49.)
(C) 10-28 - Severance pay agreement between Ohio Edison Company and
A. J. Alexander. (1995 Form 10-K, Exhibit 10-50.)
(C) 10-29 - Severance pay agreement between Ohio Edison Company and
J. A. Gill. (1995 Form 10K, Exhibit 10-51.)
(D) 10-30 - Participation Agreement dated as of March 16, 1987 among
Perry One Alpha Limited Partnership, as Owner
Participant, the Original Loan Participants listed in
Schedule 1 Hereto, as Original Loan Participants, PNPP
Funding Corporation, as Funding Corporation, The First
National Bank of Boston, as Owner Trustee, Irving Trust
Company, as Indenture Trustee and Ohio Edison Company,
as Lessee. (1986 Form 10-K, Exhibit 28-1.)
(D) 10-31 - Amendment No. 1 dated as of September 1, 1987 to
Participation Agreement dated as of March 16, 1987 among
Perry One Alpha Limited Partnership, as Owner
Participant, the Original Loan Participants listed in
Schedule 1 thereto, as Original Loan Participants, PNPP
Funding Corporation, as Funding Corporation, The First
National Bank of Boston, as Owner Trustee, Irving Trust
Company (now The Bank of New York), as Indenture
Trustee, and Ohio Edison Company, as Lessee. (1991 Form
10-K, Exhibit 10-46.)
(D) 10-32 - Amendment No. 3 dated as of May 16, 1988 to
Participation Agreement dated as of March 16, 1987, as
amended among Perry One Alpha Limited Partnership, as
Owner Participant, PNPP Funding Corporation, The First
National Bank of Boston, as Owner Trustee, Irving Trust
Company, as Indenture Trustee, and Ohio Edison Company,
as Lessee. (1992 Form 10-K, Exhibit 10-47.)
(D) 10-33 - Amendment No. 4 dated as of November 1, 1991 to
Participation Agreement dated as of March 16, 1987 among
Perry One Alpha Limited Partnership, as Owner
Participant, PNPP Funding Corporation, as Funding
Corporation, PNPP II Funding Corporation, as New Funding
Corporation, The First National Bank of Boston, as Owner
Trustee, The Bank of New York, as Indenture Trustee and
Ohio Edison Company, as Lessee. (1991 Form 10-K, Exhibit
10-47.)
(D) 10-34 - Amendment No. 5 dated as of November 24, 1992 to
Participation Agreement dated as of March 16, 1987, as
amended, among Perry One Alpha Limited Partnership, as
Owner Participant, PNPP Funding Corporation, as Funding
Corporation, PNPP II Funding Corporation, as New Funding
Corporation, The First National Bank of Boston, as Owner
Trustee, The Bank of New York, as Indenture Trustee and
Ohio Edison Company as Lessee. (1992 Form 10-K, Exhibit
10-49.)
25
(D) 10-35 - Amendment No. 6 dated as of January 12, 1993 to
Participation Agreement dated as of March 16, 1987 among
Perry One Alpha Limited Partnership, as Owner
Participant, PNPP Funding Corporation, as Funding
Corporation, PNPP II Funding Corporation, as New Funding
Corporation, The First National Bank of Boston, as Owner
Trustee, The Bank of New York, as Indenture Trustee and
Ohio Edison Company, as Lessee. (1992 Form 10-K, Exhibit
10-50.)
(D) 10-36 - Amendment No. 7 dated as of October 12, 1994 to
Participation Agreement dated as of March 16, 1987 as
amended, among Perry One Alpha Limited Partnership, as
Owner Participant, PNPP Funding Corporation, as Funding
Corporation, PNPP II Funding Corporation, as New Funding
Corporation, The First National Bank of Boston, as Owner
Trustee, The Bank of New York, as Indenture Trustee and
Ohio Edison Company, as Lessee. (1994 Form 10-K, Exhibit
10-54.)
(D) 10-37 - Facility Lease dated as of March 16, 1987 between The
First National Bank of Boston, as Owner Trustee, with
Perry One Alpha Limited Partnership, Lessor, and Ohio
Edison Company, Lessee. (1986 Form 10-K, Exhibit 28-2.)
(D) 10-38 - Amendment No. 1 dated as of September 1, 1987 to
Facility Lease dated as of March 16, 1997 between The
First National Bank of Boston, as Owner Trustee, Lessor
and Ohio Edison Company, Lessee. (1991 Form 10-K,
Exhibit 10-49.)
(D) 10-39 - Amendment No. 2 dated as of November 1, 1991, to
Facility Lease dated as of March 16, 1987, between The
First National Bank of Boston, as Owner Trustee, Lessor
and Ohio Edison Company, Lessee. (1991 Form 10-K,
Exhibit 10-50.)
(D) 10-40 - Amendment No. 3 dated as of November 24, 1992 to
Facility Lease dated as March 16, 1987 as amended,
between The First National Bank of Boston, as Owner
Trustee, with Perry One Alpha Limited partnership, as
Owner Participant and Ohio Edison Company, as Lessee.
(1992 Form 10-K, Exhibit 10-54.)
(D) 10-41 - Amendment No. 4 dated as of January 12, 1993 to Facility
Lease dated as of March 16, 1987 as amended, between,
The First National Bank of Boston, as Owner Trustee,
with Perry One Alpha Limited Partnership, as Owner
Participant, and Ohio Edison Company, as Lessee. (1994
Form 10-K, Exhibit 10-59.)
(D) 10-42 - Amendment No. 5 dated as of October 12, 1994 to Facility
Lease dated as of March 16, 1987 as amended, between,
The First National Bank of Boston, as Owner Trustee,
with Perry One Alpha Limited Partnership, as Owner
Participant, and Ohio Edison Company, as Lessee. (1994
Form 10-K, Exhibit 10-60.)
(D) 10-43 - Letter Agreement dated as of March 19, 1987 between Ohio
Edison Company, Lessee, and The First National Bank of
Boston, Owner Trustee under a Trust dated March 16, 1987
with Chase Manhattan Realty Leasing Corporation,
required by Section 3(d) of the Facility Lease. (1986
Form 10-K, Exhibit 28-3.)
(D) 10-44 - Ground Lease dated as of March 16, 1987 between Ohio
Edison Company, Ground Lessor, and The First National
Bank of Boston, as Owner Trustee under a Trust
Agreement, dated as of March 16, 1987, with the Owner
Participant, Tenant. (1986 Form 10-K, Exhibit 28-4.)
(D) 10-45 - Trust Agreement dated as of March 16, 1987 between Perry
One Alpha Limited Partnership, as Owner Participant, and
The First National Bank of Boston. (1986 Form 10-K,
Exhibit 28-5.)
(D) 10-46 - Trust Indenture, Mortgage, Security Agreement and
Assignment of Facility Lease dated as of March 16, 1987
between The First National Bank of Boston, as Owner
Trustee under a Trust Agreement dated as of March 16,
1987 with Perry One Alpha Limited Partnership, and
Irving Trust Company, as Indenture Trustee. (1986 Form
10-K, Exhibit 28-6.)
(D) 10-47 - Supplemental Indenture No. 1 dated as of September 1,
1987 to Trust Indenture, Mortgage, Security Agreement
and Assignment of Facility Lease dated as of March 16,
1987 between The First National Bank of Boston as Owner
Trustee and Irving Trust Company (now The Bank of New
York), as Indenture Trustee. (1991 Form 10-K, Exhibit
10-55.)
(D) 10-48 - Supplemental Indenture No. 2 dated as of November 1,
1991 to Trust Indenture, Mortgage, Security Agreement
and Assignment of Facility Lease dated as of March 16,
1987 between The
26
First National Bank of Boston, as Owner Trustee and The
Bank of New York, as Indenture Trustee. (1991 Form 10-K,
Exhibit 10-56.)
(D) 10-49 - Tax Indemnification Agreement dated as of March 16, 1987
between Perry One, Inc. and PARock Limited Partnership
as General Partners and Ohio Edison Company, as Lessee.
(1986 Form 10-K, Exhibit 28-7.)
(D) 10-50 - Amendment No. 1 dated as of November 1, 1991 to Tax
Indemnification Agreement dated as of March 16, 1987
between Perry One, Inc. and PARock Limited Partnership
and Ohio Edison Company. (1991 Form 10-K, Exhibit
10-58.)
(D) 10-51 - Amendment No. 2 dated as of January 12, 1993 to Tax
Indemnification Agreement dated as of March 16, 1987
between Perry One, Inc. and PARock Limited Partnership
and Ohio Edison Company. (1994 Form 10-K, Exhibit
10-69.)
(D) 10-52 - Amendment No. 3 dated as of October 12, 1994 to Tax
Indemnification Agreement dated as of March 16, 1987
between Perry One, Inc. and PARock Limited Partnership
and Ohio Edison Company. (1994 Form 10-K, Exhibit
10-70.)
(D) 10-53 - Partial Mortgage Release dated as of March 19, 1987
under the Indenture between Ohio Edison Company and
Bankers Trust Company, as Trustee, dated as of the 1st
day of August 1930. (1986 Form 10-K, Exhibit 28-8.)
(D) 10-54 - Assignment, Assumption and Further Agreement dated as of
March 16, 1987 among The First National Bank of Boston,
as Owner Trustee under a Trust Agreement, dated as of
March 16, 1987, with Perry One Alpha Limited
Partnership, The Cleveland Electric Illuminating
Company, Duquesne Light Company, Ohio Edison Company,
Pennsylvania Power Company and Toledo Edison Company.
(1986 Form 10-K, Exhibit 28-9.)
(D) 10-55 - Additional Support Agreement dated as of March 16, 1987
between The First National Bank of Boston, as Owner
Trustee under a Trust Agreement, dated as of March 16,
1987, with Perry One Alpha Limited Partnership, and Ohio
Edison Company. (1986 Form 10-K, Exhibit 28-10.)
(D) 10-56 - Bill of Sale, Instrument of Transfer and Severance
Agreement dated as of March 19, 1987 between Ohio Edison
Company, Seller, and The First National Bank of Boston,
as Owner Trustee under a Trust Agreement, dated as of
March 16, 1987, with Perry One Alpha Limited
Partnership. (1986 Form 10-K, Exhibit 28-11.)
(D) 10-57 - Easement dated as of March 16, 1987 from Ohio Edison
Company, Grantor, to The First National Bank of Boston,
as Owner Trustee under a Trust Agreement, dated as of
March 16, 1987, with Perry One Alpha Limited
Partnership, Grantee. (1986 Form 10-K, File Exhibit
28-12.)
10-58 - Participation Agreement dated as of March 16, 1987 among
Security Pacific Capital Leasing Corporation, as Owner
Participant, the Original Loan Participants listed in
Schedule 1 Hereto, as Original Loan Participants, PNPP
Funding Corporation, as Funding Corporation, The First
National Bank of Boston, as Owner Trustee, Irving Trust
Company, as Indenture Trustee and Ohio Edison Company,
as Lessee. (1986 Form 10-K, as Exhibit 28-13.)
10-59 - Amendment No. 1 dated as of September 1, 1987 to
Participation Agreement dated as of March 16, 1987 among
Security Pacific Capital Leasing Corporation, as Owner
Participant, The Original Loan Participants Listed in
Schedule 1 thereto, as Original Loan Participants, PNPP
Funding Corporation, as Funding Corporation, The First
National Bank of Boston, as Owner Trustee, Irving Trust
Company, as Indenture Trustee and Ohio Edison Company,
as Lessee. (1991 Form 10-K, Exhibit 10-65.)
10-60 - Amendment No. 4 dated as of November 1, 1991, to
Participation Agreement dated as of March 16, 1987 among
Security Pacific Capital Leasing Corporation, as Owner
Participant, PNPP Funding Corporation, as Funding
Corporation, PNPP II Funding Corporation, as New Funding
Corporation, The First National Bank of Boston, as Owner
Trustee, The Bank of New York, as Indenture Trustee and
Ohio Edison Company, as Lessee. (1991 Form 10-K, Exhibit
10-66.)
10-61 - Amendment No. 5 dated as of November 24, 1992 to
Participation Agreement dated as of March 16, 1987 as
amended among Security Pacific Capital Leasing
Corporation, as Owner
27
Participant, PNPP Funding Corporation, as Funding
Corporation, PNNP II Funding Corporation, as New Funding
Corporation, The First National Bank of Boston, as Owner
Trustee, The Bank of New York, as Indenture Trustee and
Ohio Edison Company, as Lessee. (1992 Form 10-K, Exhibit
10-71.)
10-62 - Amendment No. 6 dated as of January 12, 1993 to
Participation Agreement dated as of March 16, 1987 as
amended among Security Pacific Capital Leasing
Corporation, as Owner Participant, PNPP Funding
Corporation, as Funding Corporation, PNPP II Funding
Corporation, as New Funding Corporation, The First
National Bank of Boston, as Owner Trustee, The Bank of
New York, as Indenture Trustee and Ohio Edison Company,
as Lessee. (1994 Form 10-K, Exhibit 10-80.)
10-63 - Amendment No. 7 dated as of October 12, 1994 to
Participation Agreement dated as of March 16, 1987 as
amended among Security Pacific Capital Leasing
Corporation, as Owner Participant, PNPP Funding
Corporation, as Funding Corporation, PNPP II Funding
Corporation, as New Funding Corporation, The First
National Bank of Boston, as Owner Trustee, The Bank of
New York, as Indenture Trustee and Ohio Edison Company,
as Lessee. (1994 Form 10-K, Exhibit 10-81.)
10-64 - Facility Lease dated as of March 16, 1987 between The
First National Bank of Boston, as Owner Trustee, with
Security Pacific Capital Leasing Corporation, Lessor,
and Ohio Edison Company, as Lessee. (1986 Form 10-K,
Exhibit 28-14.)
10-65 - Amendment No. 1 dated as of September 1, 1987 to
Facility Lease dated as of March 16, 1987 between The
First National Bank of Boston as Owner Trustee, Lessor
and Ohio Edison Company, Lessee. (1991 Form 10-K,
Exhibit 10-68.)
10-66 - Amendment No. 2 dated as of November 1, 1991 to Facility
Lease dated as of March 16, 1987 between The First
National Bank of Boston as Owner Trustee, Lessor and
Ohio Edison Company, Lessee. (1991 Form 10-K, Exhibit
10-69.)
10-67 - Amendment No. 3 dated as of November 24, 1992 to
Facility Lease dated as of March 16, 1987, as amended,
between, The First National Bank of Boston, as Owner
Trustee, with Security Pacific Capital Leasing
Corporation, as Owner Participant and Ohio Edison
Company, as Lessee. (1992 Form 10-K, Exhibit 10-75.)
10-68 - Amendment No. 4 dated as of January 12, 1993 to Facility
Lease dated as of March 16, 1987 as amended between, The
First National Bank of Boston, as Owner Trustee, with
Security Pacific Capital Leasing Corporation, as Owner
Participant, and Ohio Edison Company, as Lessee. (1992
Form 10-K, Exhibit 10-76.)
10-69 - Amendment No. 5 dated as of October 12, 1994 to Facility
Lease dated as of March 16, 1987 as amended between, The
First National Bank of Boston, as Owner Trustee, with
Security Pacific Capital Leasing Corporation, as Owner
Participant, and Ohio Edison Company, as Lessee. (1994
Form 10-K, Exhibit 10-87.)
10-70 - Letter Agreement dated as of March 19, 1987 between Ohio
Edison Company, as Lessee, and The First National Bank
of Boston, as Owner Trustee under a Trust, dated as of
March 16, 1987, with Security Pacific Capital Leasing
Corporation, required by Section 3(d) of the Facility
Lease. (1986 Form 10-K, Exhibit 28-15.)
10-71 - Ground Lease dated as of March 16, 1987 between Ohio
Edison Company, Ground Lessor, and The First National
Bank of Boston, as Owner Trustee under a Trust
Agreement, dated as of March 16, 1987, with Perry One
Alpha Limited Partnership, Tenant. (1986 Form 10-K,
Exhibit 28-16.)
10-72 - Trust Agreement dated as of March 16, 1987 between
Security Pacific Capital Leasing Corporation, as Owner
Participant, and The First National Bank of Boston.
(1986 Form 10-K, Exhibit 28-17.)
10-73 - Trust Indenture, Mortgage, Security Agreement and
Assignment of Facility Lease dated as of March 16, 1987
between The First National Bank of Boston, as Owner
Trustee under a Trust
28
Agreement, dated as of March 16, 1987, with Security
Pacific Capital Leasing Corporation, and Irving Trust
Company, as Indenture Trustee. (1986 Form 10-K, Exhibit
28-18.)
10-74 - Supplemental Indenture No. 1 dated as of September 1,
1987 to Trust Indenture, Mortgage, Security Agreement
and Assignment of Facility Lease dated as of March 16,
1987 between The First National Bank of Boston, as Owner
Trustee and Irving Trust Company (now The Bank of New
York), as Indenture Trustee. (1991 Form 10-K, Exhibit
10-74.)
10-75 - Supplemental Indenture No. 2 dated as of November 1,
1991 to Trust Indenture, Mortgage, Security Agreement
and Assignment of Facility Lease dated as of March 16,
1987 between The First National Bank of Boston, as Owner
Trustee and The Bank of New York, as Indenture Trustee.
(1991 Form 10-K, Exhibit 10-75.)
10-76 - Tax Indemnification Agreement dated as of March 16, 1987
between Security Pacific Capital Leasing Corporation, as
Owner Participant, and Ohio Edison Company, as Lessee.
(1986 Form 10-K, Exhibit 28-19.)
10-77 - Amendment No. 1 dated as of November 1, 1991 to Tax
Indemnification Agreement dated as of March 16, 1987
between Security Pacific Capital Leasing Corporation and
Ohio Edison Company. (1991 Form 10-K, Exhibit 10-77.)
10-78 - Amendment No. 2 dated as of January 12, 1993 to Tax
Indemnification Agreement dated as of March 16, 1987
between Security Pacific Capital Leasing Corporation and
Ohio Edison Company. (1994 Form 10-K, Exhibit 10-96.)
10-79 - Amendment No. 3 dated as of October 12, 1994 to Tax
Indemnification Agreement dated as of March 16, 1987
between Security Pacific Capital Leasing Corporation and
Ohio Edison Company. (1994 Form 10-K, Exhibit 10-97.)
10-80 - Assignment, Assumption and Further Agreement dated as of
March 16, 1987 among The First National Bank of Boston,
as Owner Trustee under a Trust Agreement, dated as of
March 16, 1987, with Security Pacific Capital Leasing
Corporation, The Cleveland Electric Illuminating
Company, Duquesne Light Company, Ohio Edison Company,
Pennsylvania Power Company and Toledo Edison Company.
(1986 Form 10-K, Exhibit 28-20.)
10-81 - Additional Support Agreement dated as of March 16, 1987
between The First National Bank of Boston, as Owner
Trustee under a Trust Agreement, dated as of March 16,
1987, with Security Pacific Capital Leasing Corporation,
and Ohio Edison Company. (1986 Form 10-K, Exhibit
28-21.)
10-82 - Bill of Sale, Instrument of Transfer and Severance
Agreement dated as of March 19, 1987 between Ohio Edison
Company, Seller, and The First National Bank of Boston,
as Owner Trustee under a Trust Agreement, dated as of
March 16, 1987, with Security Pacific Capital Leasing
Corporation, Buyer. (1986 Form 10-K, Exhibit 28-22.)
10-83 - Easement dated as of March 16, 1987 from Ohio Edison
Company, Grantor, to The First National Bank of Boston,
as Owner Trustee under a Trust Agreement, dated as of
March 16, 1987, with Security Pacific Capital Leasing
Corporation, Grantee. (1986 Form 10-K, Exhibit 28-23.)
10-84 - Refinancing Agreement dated as of November 1, 1991 among
Perry One Alpha Limited Partnership, as Owner
Participant, PNPP Funding Corporation, as Funding
Corporation, PNPP II Funding Corporation, as New Funding
Corporation, The First National Bank of Boston, as Owner
Trustee, The Bank of New York, as Indenture Trustee, The
Bank of New York, as Collateral Trust Trustee, The Bank
of New York, as New Collateral Trust Trustee and Ohio
Edison Company, as Lessee. (1991 Form 10-K, Exhibit
10-82.)
10-85 - Refinancing Agreement dated as of November 1, 1991 among
Security Pacific Leasing Corporation, as Owner
Participant, PNPP Funding Corporation, as Funding
Corporation, PNPP II Funding Corporation, as New Funding
Corporation, The First National Bank of Boston, as Owner
Trustee, The Bank of New York, as Indenture Trustee, The
Bank of New York, as Collateral Trust Trustee, The Bank
of New York as New Collateral Trust Trustee and Ohio
Edison Company, as Lessee. (1991 Form 10-K, Exhibit
10-83.)
29
10-86 - Ohio Edison Company Master Decommissioning Trust
Agreement for Perry Nuclear Power Plant Unit One, Perry
Nuclear Power Plant Unit Two, Beaver Valley Power
Station Unit One and Beaver Valley Power Station Unit
Two dated July 1, 1993. (1993 Form 10-K, Exhibit 10-94.)
10-87 - Nuclear Fuel Lease dated as of March 31, 1989, between
OES Fuel, Incorporated, as Lessor, and Ohio Edison
Company, as Lessee. (1989 Form 10-K, Exhibit 10-62.)
10-88 - Receivables Purchase Agreement dated as November 28,
1989, as amended and restated as of April 23, 1993,
between OES Capital, Incorporated, Corporate Asset
Funding Company, Inc. and Citicorp North America, Inc.
(1994 Form 10-K, Exhibit 10-106.)
10-89 - Guarantee Agreement entered into by Ohio Edison Company
dated as of January 17, 1991. (1990 Form 10-K, Exhibit
10-64.)
10-90 - Transfer and Assignment Agreement among Ohio Edison
Company and Chemical Bank, as trustee under the OE Power
Contract Trust. (1990 Form 10-K, Exhibit 10-65.)
10-91 - Renunciation of Payments and Assignment among Ohio
Edison Company, Monongahela Power Company, West Penn
Power Company, and the Potomac Edison Company dated as
of January 4, 1991. (1990 Form 10-K, Exhibit 10-66.)
10-92 - Transfer and Assignment Agreement dated May 20, 1994
among Ohio Edison Company and Chemical Bank, as trustee
under the OE Power Contract Trust. (1994 Form 10-K,
Exhibit 10-110.)
10-93 - Renunciation of Payments and Assignment among Ohio
Edison Company, Monongahela Power Company, West Penn
Power Company, and the Potomac Edison Company dated as
of May 20, 1994. (1994 Form 10-K, Exhibit 10-111.)
10-94 - Transfer and Assignment Agreement dated October 12, 1994
among Ohio Edison Company and Chemical Bank, as trustee
under the OE Power Contract Trust. (1994 Form 10-K,
Exhibit 10-112.)
10-95 - Renunciation of Payments and Assignment among Ohio
Edison Company, Monongahela Power Company, West Penn
Power Company, and the Potomac Edison Company dated as
of October 12, 1994. (1994 Form 10-K, Exhibit 10-113.)
(E) 10-96 - Participation Agreement dated as of September 15, 1987,
among Beaver Valley Two Pi Limited Partnership, as Owner
Participant, the Original Loan Participants listed in
Schedule 1 Thereto, as Original Loan Participants, BVPS
Funding Corporation, as Funding Corporation, The First
National Bank of Boston, as Owner Trustee, Irving Trust
Company, as Indenture Trustee and Ohio Edison Company as
Lessee. (1987 Form 10-K, Exhibit 28-1.)
(E) 10-97 - Amendment No. 1 dated as of February 1, 1988, to
Participation Agreement dated as of September 15, 1987,
among Beaver Valley Two Pi Limited Partnership, as Owner
Participant, the Original Loan Participants listed in
Schedule 1 Thereto, as Original Loan Participants, BVPS
Funding Corporation, as Funding Corporation, The First
National Bank of Boston, as Owner Trustee, Irving Trust
Company, as Indenture Trustee and Ohio Edison Company,
as Lessee. (1987 Form 10-K, Exhibit 28-2.)
(E) 10-98 - Amendment No. 3 dated as of March 16, 1988 to
Participation Agreement dated as of September 15, 1987,
as amended, among Beaver Valley Two Pi Limited
Partnership, as Owner Participant, BVPS Funding
Corporation, The First National Bank of Boston, as Owner
Trustee, Irving Trust Company, as Indenture Trustee and
Ohio Edison Company, as Lessee. (1992 Form 10-K, Exhibit
10-99.)
(E) 10-99 - Amendment No. 4 dated as of November 5, 1992 to
Participation Agreement dated as of September 15, 1987,
as amended, among Beaver Valley Two Pi Limited
Partnership, as Owner Participant, BVPS Funding
Corporation, BVPS II Funding Corporation, The First
National Bank of Boston, as Owner Trustee, The Bank of
New York, as Indenture Trustee and Ohio Edison Company,
as Lessee. (1992 Form 10-K, Exhibit 10-100.)
(E) 10-100 - Amendment No. 5 dated as of September 30, 1994 to
Participation Agreement dated as of September 15, 1987,
as amended, among Beaver Valley Two Pi Limited
Partnership, as Owner Participant, BVPS Funding
Corporation, BVPS II Funding Corporation, The First
National Bank of
30
Boston, as Owner Trustee, The Bank of New York, as
Indenture Trustee and Ohio Edison Company, as Lessee.
(1994 Form 10-K, Exhibit 10-118.)
(E) 10-101 - Facility Lease dated as of September 15, 1987, between
The First National Bank of Boston, as Owner Trustee,
with Beaver Valley Two Pi Limited Partnership, Lessor,
and Ohio Edison Company, Lessee. (1987 Form 10-K,
Exhibit 28-3.)
(E) 10-102 - Amendment No. 1 dated as of February 1, 1988, to
Facility Lease dated as of September 15, 1987, between
The First National Bank of Boston, as Owner Trustee,
with Beaver Valley Two Pi Limited Partnership, Lessor,
and Ohio Edison Company, Lessee. (1987 Form 10-K,
Exhibit 28-4.)
(E) 10-103 - Amendment No. 2 dated as of November 5, 1992, to
Facility Lease dated as of September 15, 1987, as
amended, between The First National Bank of Boston, as
Owner Trustee, with Beaver Valley Two Pi Limited
Partnership, as Owner Participant, and Ohio Edison
Company, as Lessee. (1992 Form 10-K, Exhibit 10-103.)
(E) 10-104 - Amendment No. 3 dated as of September 30, 1994 to
Facility Lease dated as of September 15, 1987, as
amended, between The First National Bank of Boston, as
Owner Trustee, with Beaver Valley Two Pi Limited
Partnership, as Owner Participant, and Ohio Edison
Company, as Lessee. (1994 Form 10-K, Exhibit 10-122.)
(E) 10-105 - Ground Lease and Easement Agreement dated as of
September 15, 1987, between Ohio Edison Company, Ground
Lessor, and The First National Bank of Boston, as Owner
Trustee under a Trust Agreement, dated as of September
15, 1987, with Beaver Valley Two Pi Limited Partnership,
Tenant. (1987 Form 10-K, Exhibit 28-5.)
(E) 10-106 - Trust Agreement dated as of September 15, 1987, between
Beaver Valley Two Pi Limited Partnership, as Owner
Participant, and The First National Bank of Boston.
(1987 Form 10-K, Exhibit 28-6.)
(E) 10-107 - Trust Indenture, Mortgage, Security Agreement and
Assignment of Facility Lease dated as of September 15,
1987, between The First National Bank of Boston, as
Owner Trustee under a Trust Agreement dated as of
September 15, 1987, with Beaver Valley Two Pi Limited
Partnership, and Irving Trust Company, as Indenture
Trustee. (1987 Form 10-K, Exhibit 28-7.)
(E) 10-108 - Supplemental Indenture No. 1 dated as of February 1,
1988 to Trust Indenture, Mortgage, Security Agreement
and Assignment of Facility Lease dated as of September
15, 1987 between The First National Bank of Boston, as
Owner Trustee under a Trust Agreement dated as of
September 15, 1987 with Beaver Valley Two Pi Limited
Partnership and Irving Trust Company, as Indenture
Trustee. (1987 Form 10-K, Exhibit 28-8.)
(E) 10-109 - Tax Indemnification Agreement dated as of September 15,
1987, between Beaver Valley Two Pi Inc. and PARock
Limited Partnership as General Partners and Ohio Edison
Company, as Lessee. (1987 Form 10-K, Exhibit 28-9.)
(E) 10-110 - Amendment No. 1 dated as of November 5, 1992 to Tax
Indemnification Agreement dated as of September 15,
1987, between Beaver Valley Two Pi Inc. and PARock
Limited Partnership as General Partners and Ohio Edison
Company, as Lessee. (1994 Form 10-K, Exhibit 10-128.)
(E) 10-111 - Amendment No. 2 dated as of September 30, 1994 to Tax
Indemnification Agreement dated as of September 15,
1987, between Beaver Valley Two Pi Inc. and PARock
Limited Partnership as General Partners and Ohio Edison
Company, as Lessee. (1994 Form 10-K, Exhibit 10-129.)
(E) 10-112 - Tax Indemnification Agreement dated as of September 15,
1987, between HG Power Plant, Inc., as Limited Partner
and Ohio Edison Company, as Lessee. (1987 Form 10-K,
Exhibit 28-10.)
(E) 10-113 - Amendment No. 1 dated as of November 5, 1992 to Tax
Indemnification Agreement dated as of September 15,
1987, between HG Power Plant, Inc., as Limited Partner
and Ohio Edison Company, as Lessee. (1994 Form 10-K,
Exhibit 10-131.)
(E) 10-114 - Amendment No. 2 dated as of September 30, 1994 to Tax
Indemnification Agreement dated as of September 15,
1987, between HG Power Plant, Inc., as Limited Partner
and Ohio Edison Company, as Lessee. (1994 Form 10-K,
Exhibit 10-132.)
31
(E) 10-115 - Assignment, Assumption and Further Agreement dated as of
September 15, 1987, among The First National Bank of
Boston, as Owner Trustee under a Trust Agreement, dated
as of September 15, 1987, with Beaver Valley Two Pi
Limited Partnership, The Cleveland Electric Illuminating
Company, Duquesne Light Company, Ohio Edison Company,
Pennsylvania Power Company and Toledo Edison Company.
(1987 Form 10-K, Exhibit 28-11.)
(E) 10-116 - Additional Support Agreement dated as of September 15,
1987, between The First National Bank of Boston, as
Owner Trustee under a Trust Agreement, dated as of
September 15, 1987, with Beaver Valley Two Pi Limited
Partnership, and Ohio Edison Company. (1987 Form 10-K,
Exhibit 28-12.)
(F) 10-117 - Participation Agreement dated as of September 15, 1987,
among Chrysler Consortium Corporation, as Owner
Participant, the Original Loan Participants listed in
Schedule 1 Thereto, as Original Loan Participants, BVPS
Funding Corporation as Funding Corporation, The First
National Bank of Boston, as Owner Trustee, Irving Trust
Company, as Indenture Trustee and Ohio Edison Company,
as Lessee. (1987 Form 10-K, Exhibit 28-13.)
(F) 10-118 - Amendment No. 1 dated as of February 1, 1988, to
Participation Agreement dated as of September 15, 1987,
among Chrysler Consortium Corporation, as Owner
Participant, the Original Loan Participants listed in
Schedule 1 Thereto, as Original Loan Participants, BVPS
Funding Corporation, as Funding Corporation, The First
National Bank of Boston, as Owner Trustee, Irving Trust
Company, as Indenture Trustee, and Ohio Edison Company,
as Lessee. (1987 Form 10-K, Exhibit 28-14.)
(F) 10-119 - Amendment No. 3 dated as of March 16, 1988 to
Participation Agreement dated as of September 15, 1987,
as amended, among Chrysler Consortium Corporation, as
Owner Participant, BVPS Funding Corporation, The First
National Bank of Boston, as Owner Trustee, Irving Trust
Company, as Indenture Trustee, and Ohio Edison Company,
as Lessee. (1992 Form 10-K, Exhibit 10-114.)
(F) 10-120 - Amendment No. 4 dated as of November 5, 1992 to
Participation Agreement dated as of September 15, 1987,
as amended, among Chrysler Consortium Corporation, as
Owner Participant, BVPS Funding Corporation, BVPS II
Funding Corporation, The First National Bank of Boston,
as Owner Trustee, The Bank of New York, as Indenture
Trustee and Ohio Edison Company, as Lessee. (1992 Form
10-K, Exhibit 10-115.)
(F) 10-121 - Amendment No. 5 dated as of January 12, 1993 to
Participation Agreement dated as of September 15, 1987,
as amended, among Chrysler Consortium Corporation, as
Owner Participant, BVPS Funding Corporation, BVPS II
Funding Corporation, The First National Bank of Boston,
as Owner Trustee, The Bank of New York, as Indenture
Trustee and Ohio Edison Company, as Lessee. (1994 Form
10-K, Exhibit 10-139.)
(F) 10-122 - Amendment No. 6 dated as of September 30, 1994 to
Participation Agreement dated as of September 15, 1987,
as amended, among Chrysler Consortium Corporation, as
Owner Participant, BVPS Funding Corporation, BVPS II
Funding Corporation, The First National Bank of Boston,
as Owner Trustee, The Bank of New York, as Indenture
Trustee and Ohio Edison Company, as Lessee. (1994 Form
10-K, Exhibit 10-140.)
(F) 10-123 - Facility Lease dated as of September 15, 1987, between
The First National Bank of Boston, as Owner Trustee,
with Chrysler Consortium Corporation, Lessor, and Ohio
Edison Company, as Lessee. (1987 Form 10-K, Exhibit
28-15.)
(F) 10-124 - Amendment No. 1 dated as of February 1, 1988, to
Facility Lease dated as of September 15, 1987, between
The First National Bank of Boston, as Owner Trustee,
with Chrysler Consortium Corporation, Lessor, and Ohio
Edison Company, Lessee. (1987 Form 10-K, Exhibit 28-16.)
(F) 10-125 - Amendment No. 2 dated as of November 5, 1992 to Facility
Lease dated as of September 15, 1987, as amended,
between The First National Bank of Boston, as Owner
Trustee, with Chrysler Consortium Corporation, as Owner
Participant, and Ohio Edison Company, as Lessee. (1992
Form 10-K, Exhibit 10-118.)
32
(F) 10-126 - Amendment No. 3 dated as of January 12, 1993 to Facility
Lease dated as of September 15, 1987, as amended,
between The First National Bank of Boston, as Owner
Trustee, with Chrysler Consortium Corporation, as Owner
Participant, and Ohio Edison Company, as Lessee. (1992
Form 10-K, Exhibit 10-119.)
(F) 10-127 - Amendment No. 4 dated as of September 30, 1994 to
Facility Lease dated as of September 15, 1987, as
amended, between The First National Bank of Boston, as
Owner Trustee, with Chrysler Consortium Corporation, as
Owner Participant, and Ohio Edison Company, as Lessee.
(1994 Form 10-K, Exhibit 10-145.)
(F) 10-128 - Ground Lease and Easement Agreement dated as of
September 15, 1987, between Ohio Edison Company, Ground
Lessor, and The First National Bank of Boston, as Owner
Trustee under a Trust Agreement, dated as of September
15, 1987, with Chrysler Consortium Corporation, Tenant.
(1987 Form 10-K, Exhibit 28-17.)
(F) 10-129 - Trust Agreement dated as of September 15, 1987, between
Chrysler Consortium Corporation, as Owner Participant,
and The First National Bank of Boston. (1987 Form 10-K,
Exhibit 28-18.)
(F) 10-130 - Trust Indenture, Mortgage, Security Agreement and
Assignment of Facility Lease dated as of September 15,
1987, between The First National Bank of Boston, as
Owner Trustee under a Trust Agreement, dated as of
September 15, 1987, with Chrysler Consortium Corporation
and Irving Trust Company, as Indenture Trustee. (1987
Form 10-K, Exhibit 28-19.)
(F) 10-131 - Supplemental Indenture No. 1 dated as of February 1,
1988 to Trust Indenture, Mortgage, Security Agreement
and Assignment of Facility Lease dated as of September
15, 1987 between The First National Bank of Boston, as
Owner Trustee under a Trust Agreement dated as of
September 15, 1987 with Chrysler Consortium Corporation
and Irving Trust Company, as Indenture Trustee. (1987
Form 10-K, Exhibit 28-20.)
(F) 10-132 - Tax Indemnification Agreement dated as of September 15,
1987, between Chrysler Consortium Corporation, as Owner
Participant, and Ohio Edison Company, Lessee. (1987 Form
10-K, Exhibit 28-21.)
(F) 10-133 - Amendment No. 1 dated as of November 5, 1992 to Tax
Indemnification Agreement dated as of September 15,
1987, between Chrysler Consortium Corporation, as Owner
Participant, and Ohio Edison Company, as Lessee. (1994
Form 10-K, Exhibit 10-151.)
(F) 10-134 - Amendment No. 2 dated as of January 12, 1993 to Tax
Indemnification Agreement dated as of September 15,
1987, between Chrysler Consortium Corporation, as Owner
Participant, and Ohio Edison Company, as Lessee. (1994
Form 10-K, Exhibit 10-152.)
(F) 10-135 - Amendment No. 3 dated as of September 30, 1994 to Tax
Indemnification Agreement dated as of September 15,
1987, between Chrysler Consortium Corporation, as Owner
Participant, and Ohio Edison Company, as Lessee. (1994
Form 10-K, Exhibit 10-153.)
(F) 10-136 - Assignment, Assumption and Further Agreement dated as of
September 15, 1987, among The First National Bank of
Boston, as Owner Trustee under a Trust Agreement, dated
as of September 15, 1987, with Chrysler Consortium
Corporation, The Cleveland Electric Illuminating
Company, Duquesne Light Company, Ohio Edison Company,
Pennsylvania Power Company, and Toledo Edison Company.
(1987 Form 10-K, Exhibit 28-22.)
(F) 10-137 - Additional Support Agreement dated as of September 15,
1987, between The First National Bank of Boston, as
Owner Trustee under a Trust Agreement, dated as of
September 15, 1987, with Chrysler Consortium
Corporation, and Ohio Edison Company. (1987 Form 10-K,
Exhibit 28-23.)
10-138 - Operating Agreement dated March 10, 1987 with respect to
Perry Unit No. 1 between the CAPCO Companies. (1987 Form
10-K, Exhibit 28-24.)
10-139 - Operating Agreement for Bruce Mansfield Units Nos. 1, 2
and 3 dated as of June 1, 1976, and executed on
September 15, 1987, by and between the CAPCO Companies.
(1987 Form 10-K, Exhibit 28-25.)
33
10-140 - Operating Agreement for W. H. Sammis Unit No. 7 dated as
of September 1, 1971 by and between the CAPCO Companies.
(1987 Form 10-K, Exhibit 28-26.)
10-141 - OE-APS Power Interchange Agreement dated March 18, 1987,
by and among Ohio Edison Company and Pennsylvania Power
Company, and Monongahela Power Company and West Penn
Power Company and The Potomac Edison Company. (1987 Form
10-K, Exhibit 28-27.)
10-142 - OE-PEPCO Power Supply Agreement dated March 18, 1987, by
and among Ohio Edison Company and Pennsylvania Power
Company and Potomac Electric Power Company. (1987 Form
10-K, Exhibit 28-28.)
10-143 - Supplement No. 1 dated as of April 28, 1987, to the
OE-PEPCO Power Supply Agreement dated March 18, 1987, by
and among Ohio Edison Company, Pennsylvania Power
Company, and Potomac Electric Power Company. (1987 Form
10-K, Exhibit 28-29.)
10-144 - APS-PEPCO Power Resale Agreement dated March 18, 1987,
by and among Monongahela Power Company, West Penn Power
Company, and The Potomac Edison Company and Potomac
Electric Power Company. (1987 Form 10-K, Exhibit 28-30.)
(A) 12.2 - Consolidated fixed charge ratios.
(A) 13.1 - OE 2002 Annual Report to Stockholders (Only those
portions expressly incorporated by reference in this
Form 10-K/A are to be deemed "filed" with the SEC.)
21.1 - List of Subsidiaries of the Registrant at December 31,
2002.
(A) 23.1 - Consent of Independent Auditors.
(A) 31.1 - Certification letter from chief executive officer, as
adopted pursuant to Section 302 of the Sarbanes-Oxley
Act.
(A) 31.2 - Certification letter from chief financial officer, as
adopted pursuant to Section 302 or the Sarbanes-Oxley
Act.
(A) 32 - Certification letter from chief executive officer and
chief financial officer, as adopted pursuant to Section
906 of the Sarbanes-Oxley Act.
(A) Provided herein in electronic format as an exhibit.
(B) Pursuant to paragraph (b)(4)(iii)(A) of Item 601 of Regulation S-K, OE has
not filed as an exhibit to this Form 10-K any instrument with respect to
long-term debt if the total amount of securities authorized thereunder
does not exceed 10% of the total assets of OE and its subsidiaries on a
consolidated basis, but hereby agrees to furnish to the SEC on request any
such instruments.
(C) Management contract or compensatory plan contract or arrangement filed
pursuant to Item 601 of Regulation S-K.
(D) Substantially similar documents have been entered into relating to three
additional Owner Participants.
(E) Substantially similar documents have been entered into relating to five
additional Owner Participants.
(F) Substantially similar documents have been entered into relating to two
additional Owner Participants.
Note: Reports of OE on Forms 10-Q and 10-K are on file with the SEC under
number 1-2578.
Pursuant to Rule 14a - 3 (10) of the Securities Exchange Act of 1934, the
Company will furnish any exhibit in this Report upon the payment of the
Company's expenses in furnishing such exhibit.
34
3. EXHIBITS - COMMON EXHIBITS TO CEI AND TE
EXHIBIT
NUMBER
-------
2(a) - Agreement and Plan of Merger between Ohio Edison and
Centerior Energy dated as of September 13, 1996 (Exhibit
(2)-1, Form S-4 File No. 333-21011, filed by
FirstEnergy).
2(b) - Merger Agreement by and among Centerior Acquisition
Corp., FirstEnergy and Centerior (Exhibit (2)-3, Form
S-4 File No. 333-21011, filed by FirstEnergy).
4(a) - Rights Agreement (Exhibit 4, June 25, 1996 Form 8-K,
File Nos. 1-9130, 1-2323 and 1-3583).
4(b)(1) - Form of Note Indenture between Cleveland Electric,
Toledo Edison and The Chase Manhattan Bank, as Trustee
dated as of June 13, 1997 (Exhibit 4(c), Form S-4 File
No. 333-35931, filed by Cleveland Electric and Toledo
Edison).
4(b)(2) - Form of First Supplemental Note Indenture between
Cleveland Electric, Toledo Edison and The Chase
Manhattan Bank, as Trustee dated as of June 13, 1997
(Exhibit 4(d), Form S-4 File No. 333-35931, filed by
Cleveland Electric and Toledo Edison).
10b(1)(a) - CAPCO Administration Agreement dated November 1, 1971,
as of September 14, 1967, among the CAPCO Group members
regarding the organization and procedures for
implementing the objectives of the CAPCO Group (Exhibit
5(p), Amendment No. 1, File No. 2-42230, filed by
Cleveland Electric).
10b(1)(b) - Amendment No. 1, dated January 4, 1974, to CAPCO
Administration Agreement among the CAPCO Group members
(Exhibit 5(c)(3), File No. 2-68906, filed by Ohio
Edison).
10b(2) - CAPCO Transmission Facilities Agreement dated November
1, 1971, as of September 14, 1967, among the CAPCO Group
members regarding the installation, operation and
maintenance of transmission facilities to carry out the
objectives of the CAPCO Group (Exhibit 5(q), Amendment
No. 1, File No. 2-42230, filed by Cleveland Electric).
10b(2)(1) - Amendment No. 1 to CAPCO Transmission Facilities
Agreement, dated December 23, 1993 and effective as of
January 1, 1993, among the CAPCO Group members regarding
requirements for payment of invoices at specified times,
for payment of interest on non-timely paid invoices, for
restricting adjustment of invoices after a four-year
period, and for revising the method for computing the
Investment Responsibility charge for use of a member's
transmission facilities (Exhibit 10b(2)(1), 1993 Form
10-K, File Nos. 1-9130, 1-2323 and 1-3583).
10b(3) - CAPCO Basic Operating Agreement As Amended January 1,
1993 among the CAPCO Group members regarding coordinated
operation of the members' systems (Exhibit 10b(3), 1993
Form 10-K, File Nos. 1-9130, 1-2323 and 1-3583).
10b(4) - Agreement for the Termination or Construction of Certain
Agreement By and Among the CAPCO Group members, dated
December 23, 1993 and effective as of September 1, 1980
(Exhibit 10b(4), 1993 Form 10-K, File Nos. 1-9130,
1-2323 and 1-3583).
10b(5) - Construction Agreement, dated July 22, 1974, among the
CAPCO Group members and relating to the Perry Nuclear
Plant (Exhibit 5 (yy), File No. 2-52251, filed by Toledo
Edison).
10b(6) - Contract, dated as of December 5, 1975, among the CAPCO
Group members for the construction of Beaver Valley Unit
No. 2 (Exhibit 5 (g), File No. 2-52996, filed by
Cleveland Electric).
10b(7) - Amendment No. 1, dated May 1, 1977, to Contract, dated
as of December 5, 1975, among the CAPCO Group members
for the construction of Beaver Valley Unit No. 2
(Exhibit 5(d)(4), File No. 2-60109, filed by Ohio
Edison).
10d(1)(a) - Form of Collateral Trust Indenture among CTC Beaver
Valley Funding Corporation, Cleveland Electric, Toledo
Edison and Irving Trust Company, as Trustee (Exhibit
4(a), File No. 33-18755, filed by Cleveland Electric and
Toledo Edison).
35
10d(1)(b) - Form of Supplemental Indenture to Collateral Trust
Indenture constituting Exhibit 10d(1)(a) above,
including form of Secured Lease Obligation bond (Exhibit
4(b), File No. 33-18755, filed by Cleveland Electric and
Toledo Edison).
10d(1)(c) - Form of Collateral Trust Indenture among Beaver Valley
II Funding Corporation, The Cleveland Electric
Illuminating Company and The Toledo Edison Company and
The Bank of New York, as Trustee (Exhibit (4)(a), File
No. 33-46665, filed by Cleveland Electric and Toledo
Edison).
10d(1)(d) - Form of Supplemental Indenture to Collateral Trust
Indenture constituting Exhibit 10d(1)(c) above,
including form of Secured Lease Obligation Bond (Exhibit
(4)(b), File No. 33-46665, filed by Cleveland Electric
and Toledo Edison).
10d(2)(a) - Form of Collateral Trust Indenture among CTC Mansfield
Funding Corporation, Cleveland Electric, Toledo Edison
and IBJ Schroder Bank & Trust Company, as Trustee
(Exhibit 4(a), File No. 33-20128, filed by Cleveland
Electric and Toledo Edison).
10d(2)(b) - Form of Supplemental Indenture to Collateral Trust
Indenture constituting Exhibit 10d(2)(a) above,
including forms of Secured Lease Obligation bonds
(Exhibit 4(b), File No. 33-20128, filed by Cleveland
Electric and Toledo Edison).
10d(3)(a) - Form of Facility Lease dated as of September 15, 1987
between The First National Bank of Boston, as Owner
Trustee under a Trust Agreement dated as of September
15, 1987 with the limited partnership Owner Participant
named therein, Lessor, and Cleveland Electric and Toledo
Edison, Lessee (Exhibit 4(c), File No. 33-18755, filed
by Cleveland Electric and Toledo Edison).
10d(3)(b) - Form of Amendment No. 1 to Facility Lease constituting
Exhibit 10d(3)(a) above (Exhibit 4(e), File No.
33-18755, filed by Cleveland Electric and Toledo
Edison).
10d(4)(a) - Form of Facility Lease dated as of September 15, 1987
between The First National Bank of Boston, as Owner
Trustee under a Trust Agreement dated as of September
15, 1987 with the corporate Owner Participant named
therein, Lessor, and Cleveland Electric and Toledo
Edison, Lessees (Exhibit 4(d), File No. 33-18755, filed
by Cleveland Electric and Toledo Edison).
10d(4)(b) - Form of Amendment No. 1 to Facility Lease constituting
Exhibit 10d(4)(a) above (Exhibit 4(f), File No.
33-18755, filed by Cleveland Electric and Toledo
Edison).
10d(5)(a) - Form of Facility Lease dated as of September 30, 1987
between Meridian Trust Company, as Owner Trustee under a
Trust Agreement dated as of September 30, 1987 with the
Owner Participant named therein, Lessor, and Cleveland
Electric and Toledo Edison, Lessees (Exhibit 4(c), File
No. 33-20128, filed by Cleveland Electric and Toledo
Edison).
10d(5)(b) - Form of Amendment No. 1 to the Facility Lease
constituting Exhibit 10d(5)(a) above (Exhibit 4(f), File
No. 33-20128, filed by Cleveland Electric and Toledo
Edison).
10d(6)(a) - Form of Participation Agreement dated as of September
15, 1987 among the limited partnership Owner Participant
named therein, the Original Loan Participants listed in
Schedule 1 thereto, as Original Loan Participants, CTC
Beaver Valley Fund Corporation, as Funding Corporation,
The First National Bank of Boston, as Owner Trustee,
Irving Trust Company, as Indenture Trustee, and
Cleveland Electric and Toledo Edison, as Lessees
(Exhibit 28(a), File No. 33-18755, filed by Cleveland
Electric And Toledo Edison).
10d(6)(b) - Form of Amendment No. 1 to Participation Agreement
constituting Exhibit 10d(6)(a) above (Exhibit 28(c),
File No. 33-18755, filed by Cleveland Electric and
Toledo Edison).
10d(7)(a) - Form of Participation Agreement dated as of September
15, 1987 among the corporate Owner Participant named
therein, the Original Loan Participants listed in
Schedule 1 thereto, as Owner Loan Participants, CTC
Beaver Valley Funding Corporation, as Funding
Corporation, The First National Bank of Boston, as Owner
Trustee, Irving Trust Company, as Indenture Trustee, and
Cleveland Electric and Toledo Edison, as Lessees
(Exhibit 28(b), File No. 33-18755, filed by Cleveland
Electric and Toledo Edison).
10d(7)(b) - Form of Amendment No. 1 to Participation Agreement
constituting Exhibit 10d(7)(a) above (Exhibit 28(d),
File No. 33-18755, filed by Cleveland Electric and
Toledo Edison).
36
10d(8)(a) - Form of Participation Agreement dated as of September
30, 1987 among the Owner Participant named therein, the
Original Loan Participants listed in Schedule II
thereto, as Owner Loan Participants, CTC Mansfield
Funding Corporation, Meridian Trust Company, as Owner
Trustee, IBJ Schroder Bank & Trust Company, as Indenture
Trustee, and Cleveland Electric and Toledo Edison, as
Lessees (Exhibit 28(a), File No. 33-0128, filed by
Cleveland Electric and Toledo Edison).
10d(8)(b) - Form of Amendment No. 1 to the Participation Agreement
constituting Exhibit 10d(8)(a) above (Exhibit 28(b),
File No. 33-20128, filed by Cleveland Electric and
Toledo Edison).
10d(9) - Form of Ground Lease dated as of September 15, 1987
between Toledo Edison, Ground Lessor, and The First
National Bank of Boston, as Owner Trustee under a Trust
Agreement dated as of September 15, 1987 with the Owner
Participant named therein, Tenant (Exhibit 28(e), File
No. 33-18755, filed by Cleveland Electric and Toledo
Edison).
10d(10) - Form of Site Lease dated as of September 30, 1987
between Toledo Edison, Lessor, and Meridian Trust
Company, as Owner Trustee under a Trust Agreement dated
as of September 30, 1987 with the Owner Participant
named therein, Tenant (Exhibit 28(c), File No. 33-20128,
filed by Cleveland Electric and Toledo Edison).
10d(11) - Form of Site Lease dated as of September 30, 1987
between Cleveland Electric, Lessor, and Meridian Trust
Company, as Owner Trustee under a Trust Agreement dated
as of September 30, 1987 with the Owner Participant
named therein, Tenant (Exhibit 28(d), File No. 33-20128,
filed by Cleveland Electric and Toledo Edison).
10d(12) - Form of Amendment No. 1 to the Site Leases constituting
Exhibits 10d(10) and 10d(11) above (Exhibit 4(f), File
No. 33-20128, filed by Cleveland Electric and Toledo
Edison).
10d(13) - Form of Assignment, Assumption and Further Agreement
dated as of September 15, 1987 among The First National
Bank of Boston, as Owner Trustee under a Trust Agreement
dated as of September 15, 1987 with the Owner
Participant named therein, Cleveland Electric, Duquesne,
Ohio Edison, Pennsylvania Power and Toledo Edison
(Exhibit 28(f), File No. 33-18755, filed by Cleveland
Electric and Toledo Edison).
10d(14) - Form of Additional Support Agreement dated as of
September 15, 1987 between The First National Bank of
Boston, as Owner Trustee under a Trust Agreement dated
as of September 15, 1987 with the Owner Participant
named therein, and Toledo Edison (Exhibit 28(g), File
No. 33-18755, filed by Cleveland Electric and Toledo
Edison).
10d(15) - Form of Support Agreement dated as of September 30, 1987
between Meridian Trust Company, as Owner Trustee under a
Trust Agreement dated as of September 30, 1987 with the
Owner Participant named therein, Toledo Edison,
Cleveland Electric, Duquesne, Ohio Edison and
Pennsylvania Power (Exhibit 28(e), File No. 33-20128,
filed by Cleveland Electric and Toledo Edison).
10d(16) - Form of Indenture, Bill of Sale, Instrument of Transfer
and Severance Agreement dated as of September 30, 1987
between Toledo Edison, Seller, and The First National
Bank of Boston, as Owner Trustee under a Trust Agreement
dated as of September 15, 1987 with the Owner
Participant named therein, Buyer (Exhibit 28(h), File
No. 33-18755, filed by Cleveland Electric and Toledo
Edison).
10d(17) - Form of Bill of Sale, Instrument of Transfer and
Severance Agreement dated as of September 30, 1987
between Toledo Edison, Seller, and Meridian Trust
Company, as Owner Trustee under a Trust Agreement dated
as of September 30, 1987 with the Owner Participant
named therein, Buyer (Exhibit 28(f), File No. 33-20128,
filed by Cleveland Electric and Toledo Edison).
10d(18) - Form of Bill of Sale, Instrument of Transfer and
Severance Agreement dated as of September 30, 1987
between Cleveland Electric, Seller, and Meridian Trust
Company, as Owner Trustee under a Trust Agreement dated
as of September 30, 1987 with the Owner Participant
named therein, Buyer (Exhibit 28(g), File No. 33-20128,
filed by Cleveland Electric and Toledo Edison).
37
10d(19) - Forms of Refinancing Agreement, including exhibits
thereto, among the Owner Participant named therein, as
Owner Participant, CTC Beaver Valley Funding
Corporation, as Funding Corporation, Beaver Valley II
Funding Corporation, as New Funding Corporation, The
Bank of New York, as Indenture Trustee, The Bank of New
York, as New Collateral Trust Trustee, and The Cleveland
Electric Illuminating Company and The Toledo Edison
Company, as Lessees (Exhibit (28)(e)(i), File No.
33-46665, filed by Cleveland Electric and Toledo
Edison).
10d(20)(a) - Form of Amendment No. 2 to Facility Lease among Citicorp
Lescaman, Inc., Cleveland Electric and Toledo Edison
(Exhibit 10(a), Form S-4 File No. 333-47651, filed by
Cleveland Electric).
10d(20)(b) - Form of Amendment No. 3 to Facility Lease among Citicorp
Lescaman, Inc., Cleveland Electric and Toledo Edison
(Exhibit 10(b), Form S-4 File No. 333-47651, filed by
Cleveland Electric).
10d(21)(a) - Form of Amendment No. 2 to Facility Lease among US West
Financial Services, Inc., Cleveland Electric and Toledo
Edison (Exhibit 10(c), Form S-4 File No. 333-47651,
filed by Cleveland Electric).
10d(21)(b) - Form of Amendment No. 3 to Facility Lease among US West
Financial Services, Inc., Cleveland Electric and Toledo
Edison (Exhibit 10(d), Form S-4 File No. 333-47651,
filed by Cleveland Electric).
10d(22) - Form of Amendment No. 2 to Facility Lease among Midwest
Power Company, Cleveland Electric and Toledo Edison
(Exhibit 10(e), Form S-4 File No. 333-47651, filed by
Cleveland Electric).
10e(1) - Centerior Energy Corporation Equity Compensation Plan
(Exhibit 99, Form S-8, File No. 33-59635).
3. EXHIBITS - CLEVELAND ELECTRIC ILLUMINATING (CEI)
3a - Amended Articles of Incorporation of CEI, as amended,
effective May 28, 1993 (Exhibit 3a, 1993 Form 10-K, File
No. 1-2323).
3b - Regulations of CEI, dated April 29, 1981, as amended
effective October 1, 1988 and April 24, 1990 (Exhibit
3b, 1990 Form 10-K, File No. 1-2323).
3c - Amended and Restated Code of Regulations, dated March
15, 2002.
(B)4b(1) - Mortgage and Deed of Trust between CEI and Guaranty
Trust Company of New York (now The Chase Manhattan Bank
(National Association)), as Trustee, dated July 1, 1940
(Exhibit 7(a), File No. 2-4450).
Supplemental Indentures between CEI and the Trustee,
supplemental to Exhibit 4b(1), dated as follows:
4b(2) - July 1, 1940 (Exhibit 7(b), File No. 2-4450).
4b(3) - August 18, 1944 (Exhibit 4(c), File No. 2-9887).
4b(4) - December 1, 1947 (Exhibit 7(d), File No. 2-7306).
4b(5) - September 1, 1950 (Exhibit 7(c), File No. 2-8587).
4b(6) - June 1, 1951 (Exhibit 7(f), File No. 2-8994).
4b(7) - May 1, 1954 (Exhibit 4(d), File No. 2-10830).
4b(8) - March 1, 1958 (Exhibit 2(a)(4), File No. 2-13839).
4b(9) - April 1, 1959 (Exhibit 2(a)(4), File No. 2-14753).
4b(10) - December 20, 1967 (Exhibit 2(a)(4), File No. 2-30759).
4b(11) - January 15, 1969 (Exhibit 2(a)(5), File No. 2-30759).
4b(12) - November 1, 1969 (Exhibit 2(a)(4), File No. 2-35008).
4b(13) - June 1, 1970 (Exhibit 2(a)(4), File No. 2-37235).
4b(14) - November 15, 1970 (Exhibit 2(a)(4), File No. 2-38460).
4b(15) - May 1, 1974 (Exhibit 2(a)(4), File No. 2-50537).
4b(16) - April 15, 1975 (Exhibit 2(a)(4), File No. 2-52995).
4b(17) - April 16, 1975 (Exhibit 2(a)(4), File No. 2-53309).
4b(18) - May 28, 1975 (Exhibit 2(c), June 5, 1975 Form 8-A, File
No. 1-2323).
4b(19) - February 1, 1976 (Exhibit 3(d)(6), 1975 Form 10 K, File
No. 1-2323).
38
4b(20) - November 23, 1976 (Exhibit 2(a)(4), File No. 2-57375).
4b(21) - July 26, 1977 (Exhibit 2(a)(4), File No. 2-59401).
4b(22) - September 7, 1977 (Exhibit 2(a)(5), File No. 2-67221).
4b(23) - May 1, 1978 (Exhibit 2(b), June 30, 1978 Form 10-Q, File
No. 1-2323).
4b(24) - September 1, 1979 (Exhibit 2(a), September 30, 1979 Form
10-Q, File No. 1-2323).
4b(25) - April 1, 1980 (Exhibit 4(a)(2), September 30, 1980 Form
10-Q, File No. 1-2323).
4b(26) - April 15, 1980 (Exhibit 4(b), September 30, 1980 Form
10-Q, File No. 1-2323).
4b(27) - May 28, 1980 (Exhibit 2(a)(4), Amendment No. 1, File
No. 2-67221).
4b(28) - June 9, 1980 (Exhibit 4(d), September 30, 1980 Form
10-Q, File No. 1-2323).
4b(29) - December 1, 1980 (Exhibit 4(b)(29), 1980 Form 10-K, File
No. 1-2323).
4b(30) - July 28, 1981 (Exhibit 4(a), September 30, 1981, Form
10-Q, File No. 1-2323).
4b(31) - August 1, 1981 (Exhibit 4(b), September 30, 1981, Form
10-Q, File No. 1-2323).
4b(32) - March 1, 1982 (Exhibit 4(b)(3), Amendment No. 1, File
No. 2-76029).
4b(33) - July 15, 1982 (Exhibit 4(a), September 30, 1982 Form
10-Q, File No. 1-2323).
4b(34) - September 1, 1982 (Exhibit 4(a)(1), September 30, 1982
Form 10-Q, File No. 1-2323).
4b(35) - November 1, 1982 (Exhibit (a)(2), September 30, 1982
Form 10-Q, File No. 1-2323).
4b(36) - November 15, 1982 (Exhibit 4(b)(36), 1982 Form 10-K,
File No. 1-2323).
4b(37) - May 24, 1983 (Exhibit 4(a), June 30, 1983 Form 10-Q,
File No. 1-2323).
4b(38) - May 1, 1984 (Exhibit 4, June 30, 1984 Form 10-Q, File
No. 1-2323).
4b(39) - May 23, 1984 (Exhibit 4, May 22, 1984 Form 8-K, File No.
1-2323).
4b(40) - June 27, 1984 (Exhibit 4, June 11, 1984 Form 8-K, File
No. 1-2323).
4b(41) - September 4, 1984 (Exhibit 4b(41), 1984 Form 10-K, File
No. 1-2323).
4b(42) - November 14, 1984 (Exhibit 4b(42), 1984 Form 10 K, File
No. 1-2323).
4b(43) - November 15, 1984 (Exhibit 4b(43), 1984 Form 10-K, File
No. 1-2323).
4b(44) - April 15, 1985 (Exhibit 4(a), May 8, 1985 Form 8-K, File
No. 1-2323).
4b(45) - May 28, 1985 (Exhibit 4(b), May 8, 1985 Form 8-K, File
No. 1-2323).
4b(46) - August 1, 1985 (Exhibit 4, September 30, 1985 Form 10-Q,
File No. 1-2323).
4b(47) - September 1, 1985 (Exhibit 4, September 30, 1985 Form
8-K, File No. 1-2323).
4b(48) - November 1, 1985 (Exhibit 4, January 31, 1986 Form 8-K,
File No. 1-2323).
4b(49) - April 15, 1986 (Exhibit 4, March 31, 1986 Form 10-Q,
File No. 1-2323).
4b(50) - May 14, 1986 (Exhibit 4(a), June 30, 1986 Form 10-Q,
File No. 1-2323).
4b(51) - May 15, 1986 (Exhibit 4(b), June 30, 1986 Form 10-Q,
File No. 1-2323).
4b(52) - February 25, 1987 (Exhibit 4b(52), 1986 Form 10-K, File
No. 1-2323).
4b(53) - October 15, 1987 (Exhibit 4, September 30, 1987 Form
10-Q, File No. 1-2323).
4b(54) - February 24, 1988 (Exhibit 4b(54), 1987 Form 10-K, File
No. 1-2323).
4b(55) - September 15, 1988 (Exhibit 4b(55), 1988 Form 10-K, File
No. 1-2323).
4b(56) - May 15, 1989 (Exhibit 4(a)(2)(i), File No. 33-32724).
4b(57) - June 13, 1989 (Exhibit 4(a)(2)(ii), File No. 33-32724).
4b(58) - October 15, 1989 (Exhibit 4(a)(2)(iii), File No.
33-32724).
4b(59) - January 1, 1990 (Exhibit 4b(59), 1989 Form 10-K, File
No. 1-2323).
4b(60) - June 1, 1990 (Exhibit 4(a). September 30, 1990 Form
10-Q, File No. 1-2323).
4b(61) - August 1, 1990 (Exhibit 4(b), September 30, 1990 Form
10-Q, File No. 1-2323).
4b(62) - May 1, 1991 (Exhibit 4(a), June 30, 1991 Form 10-Q, File
No. 1-2323).
4b(63) - May 1, 1992 (Exhibit 4(a)(3), File No. 33-48845).
4b(64) - July 31, 1992 (Exhibit 4(a)(3), File No. 33-57292).
4b(65) - January 1, 1993 (Exhibit 4b(65), 1992 Form 10-K, File
No. 1-2323).
4b(66) - February 1, 1993 (Exhibit 4b(66), 1992 Form 10-K, File
No. 1-2323).
4b(67) - May 20, 1993 (Exhibit 4(a), July 14, 1993 Form 8-K, File
No. 1-2323).
4b(68) - June 1, 1993 (Exhibit 4(b), July 14, 1993 Form 8-K, File
No. 1-2323).
4b(69) - September 15, 1994 (Exhibit 4(a), September 30, 1994
Form 10-Q, File No. 1-2323).
4b(70) - May 1, 1995 (Exhibit 4(a), September 30, 1995 Form 10-Q,
File No. 1-2323).
4b(71) - May 2, 1995 (Exhibit 4(b), September 30, 1995 Form 10-Q,
File No. 1-2323).
4b(72) - June 1, 1995 (Exhibit 4(c), September 30, 1995 Form
10-Q, File No. 1-2323).
4b(73) - July 15, 1995 (Exhibit 4b(73), 1995 Form 10-K, File No.
1-2323).
4b(74) - August 1, 1995 (Exhibit 4b(74), 1995 Form 10-K, File No.
1-2323).
4b(75) - June 15, 1997 (Exhibit 4(a), Form S-4 File No.
333-35931, filed by Cleveland Electric and Toledo
Edison).
4b(76) - October 15, 1997 (Exhibit 4(a), Form S-4 File No.
333-47651, filed by Cleveland Electric).
4b(77) - June 1, 1998 (Exhibit 4b(77), Form S-4 File No.
333-72891).
4b(78) - October 1, 1998 (Exhibit 4b(78), Form S-4 File No.
333-72891).
39
4b(79) - October 1, 1998 (Exhibit 4b(79), Form S-4 File No.
333-72891).
4b(80) - February 24, 1999 (Exhibit 4b(80), Form S-4 File No.
333-72891).
4b(81) - September 29, 1999. (Exhibit 4b(81), 1999 Form 10-K,
File No. 1-2323).
4b(82) - January 15, 2000. (Exhibit 4b(82), 1999 Form 10-K, File
No. 1-2323).
4b(83) - May 15, 2002
4b(84) - October 1, 2002
4d - Form of Note Indenture between Cleveland Electric and
The Chase Manhattan Bank, as Trustee dated as of October
24, 1997 (Exhibit 4(b), Form S-4 File No. 333-47651,
filed by Cleveland Electric).
4d(1) - Form of Supplemental Note Indenture between Cleveland
Electric and The Chase Manhattan Bank, as Trustee dated
as of October 24, 1997 (Exhibit 4(c), Form S-4 File No.
333-47651, filed by Cleveland Electric).
10-1 - Administration Agreement between the CAPCO Group dated
as of September 14, 1967. (Registration No. 2-43102,
Exhibit 5(c)(2).)
10-2 - Amendment No. 1 dated January 4, 1974 to Administration
Agreement between the CAPCO Group dated as of September
14, 1967. (Registration No. 2-68906, Exhibit 5(c)(3).)
10-3 - Transmission Facilities Agreement between the CAPCO
Group dated as of September 14, 1967. (Registration No.
2-43102, Exhibit 5(c)(3).)
10-4 - Amendment No. 1 dated as of January 1, 1993 to
Transmission Facilities Agreement between the CAPCO
Group dated as of September 14, 1967. (1993 Form 10-K,
Exhibit 10-4.)
10-5 - Agreement for the Termination or Construction of Certain
Agreements effective September 1, 1980, October 15, 1997
(Exhibit 4(a), Form S-4 File No. 333-47651, filed by
Cleveland Electric).
(A) 12.3 - Consolidated fixed charge ratios.
(A) 13.2 - CEI 2002 Annual Report to Stockholders. (Only those
portions expressly incorporated by reference in this
Form 10-K/A are to be deemed "filed" with the SEC.)
21.2 - List of Subsidiaries of the Registrant at December 31,
2002.
(A) 31.1 - Certification letter from chief executive officer, as
adopted pursuant to Section 302 of the Sarbanes-Oxley
Act.
(A) 31.2 - Certification letter from chief financial officer, as
adopted pursuant to Section 302 or the Sarbanes-Oxley
Act.
(A) 32 - Certification letter from chief executive officer and
chief financial officer, as adopted pursuant to Section
906 of the Sarbanes-Oxley Act.
(A) Provided herein in electronic format as an exhibit.
(B) - Pursuant to paragraph (b)(4)(iii)(A) of Item 601 of
Regulation S-K, CEI has not filed as an exhibit to this
Form 10-K any instrument with respect to long-term debt
if the total amount of securities authorized thereunder
does not exceed 10% of the total assets of CEI, but
hereby agrees to furnish to the Commission on request
any such instruments.
3. EXHIBITS - TOLEDO EDISON (TE)
EXHIBIT
NUMBER
-------
3a - Amended Articles of Incorporation of TE, as amended
effective October 2, 1992 (Exhibit 3a, 1992 Form 10-K,
File No. 1-3583).
3b - Amended and Restated Code of Regulations, dated March
15, 2002. (2001 Form 10-K, Exhibit 3b)
40
(B)4b(1) - Indenture, dated as of April 1, 1947, between TE and The
Chase National Bank of the City of New York (now The
Chase Manhattan Bank (National Association)) (Exhibit
2(b), File No. 2-26908).
4b(2) - September 1, 1948 (Exhibit 2(d), File No. 2-26908).
4b(3) - April 1, 1949 (Exhibit 2(e), File No. 2-26908).
4b(4) - December 1, 1950 (Exhibit 2(f), File No. 2-26908).
4b(5) - March 1, 1954 (Exhibit 2(g), File No. 2-26908).
4b(6) - February 1, 1956 (Exhibit 2(h), File No. 2-26908).
4b(7) - May 1, 1958 (Exhibit 5(g), File No. 2-59794).
4b(8) - August 1, 1967 (Exhibit 2(c), File No. 2-26908).
4b(9) - November 1, 1970 (Exhibit 2(c), File No. 2-38569).
4b(10) - August 1, 1972 (Exhibit 2(c), File No. 2-44873).
4b(11) - November 1, 1973 (Exhibit 2(c), File No. 2-49428).
4b(12) - July 1, 1974 (Exhibit 2(c), File No. 2-51429).
4b(13) - October 1, 1975 (Exhibit 2(c), File No. 2-54627).
4b(14) - June 1, 1976 (Exhibit 2(c), File No. 2-56396).
4b(15) - October 1, 1978 (Exhibit 2(c), File No. 2-62568).
4b(16) - September 1, 1979 (Exhibit 2(c), File No. 2-65350).
4b(17) - September 1, 1980 (Exhibit 4(s), File No. 2-69190).
4b(18) - October 1, 1980 (Exhibit 4(c), File No. 2-69190).
4b(19) - April 1, 1981 (Exhibit 4(c), File No. 2-71580).
4b(20) - November 1, 1981 (Exhibit 4(c), File No. 2-74485).
4b(21) - June 1, 1982 (Exhibit 4(c), File No. 2-77763).
4b(22) - September 1, 1982 (Exhibit 4(x), File No. 2-87323).
4b(23) - April 1, 1983 (Exhibit 4(c), March 31, 1983, Form 10-Q,
File No. 1-3583).
4b(24) - December 1, 1983 (Exhibit 4(x), 1983 Form 10-K, File No.
1-3583).
4b(25) - April 1, 1984 (Exhibit 4(c), File No. 2-90059).
4b(26) - October 15, 1984 (Exhibit 4(z), 1984 Form 10-K, File No.
1-3583).
4b(27) - October 15, 1984 (Exhibit 4(aa), 1984 Form 10-K, File
No. 1-3583).
4b(28) - August 1, 1985 (Exhibit 4(dd), File No. 33-1689).
4b(29) - August 1, 1985 (Exhibit 4(ee), File No. 33-1689).
4b(30) - December 1, 1985 (Exhibit 4(c), File No. 33-1689).
4b(31) - March 1, 1986 (Exhibit 4b(31), 1986 Form 10-K, File No.
1-3583).
4b(32) - October 15, 1987 (Exhibit 4, September 30, 1987 Form
10-Q, File No. 1-3583).
4b(33) - September 15, 1988 (Exhibit 4b(33), 1988 Form 10-K, File
No. 1-3583).
4b(34) - June 15, 1989 (Exhibit 4b(34), 1989 Form 10-K, File No.
1-3583).
4b(35) - October 15, 1989 (Exhibit 4b(35), 1989 Form 10-K, File
No. 1-3583).
4b(36) - May 15, 1990 (Exhibit 4, June 30, 1990 Form 10-Q, File
No. 1-3583).
4b(37) - March 1, 1991 (Exhibit 4(b), June 30, 1991 Form 10-Q,
File No. 1-3583).
4b(38) - May 1, 1992 (Exhibit 4(a)(3), File No. 33-48844).
4b(39) - August 1, 1992 (Exhibit 4b(39), 1992 Form 10-K, File No.
1-3583).
4b(40) - October 1, 1992 (Exhibit 4b(40), 1992 Form 10-K, File
No. 1-3583).
4b(41) - January 1, 1993 (Exhibit 4b(41), 1992 Form 10-K, File
No. 1-3583).
4b(42) - September 15, 1994 (Exhibit 4(b), September 30, 1994
Form 10-Q, File No. 1-3583).
4b(43) - May 1, 1995 (Exhibit 4(d), September 30, 1995 Form 10-Q,
File No. 1-3583).
4b(44) - June 1, 1995 (Exhibit 4(e), September 30, 1995 Form
10-Q, File No. 1-3583).
4b(45) - July 14, 1995 (Exhibit 4(f), September 30, 1995 Form
10-Q, File No. 1-3583).
4b(46) - July 15, 1995 (Exhibit 4(g), September 30, 1995 Form
10-Q, File No. 1-3583).
4b(47) - August 1, 1997 (Exhibit 4b(47), 1998 Form 10-K, File No.
1-3583).
4b(48) - June 1, 1998 (Exhibit 4b (48), 1998 Form 10-K, File No.
1-3583).
4b(49) - January 15, 2000 (Exhibit 4b(49), 1999 Form 10-K, File
No. 1-3583).
4b(50) - May 1, 2000 (Exhibit 4b(50), 2000 Form 10-K, File No.
1-3583).
4b(51) - September 1, 2000
4b(52) - October 1, 2002
(A) 12.4 - Consolidated fixed charge ratios.
(A) 13.3 - TE 2002 Annual Report to Stockholders. (Only those
portions expressly incorporated by reference in this
Form 10-K/A are to be deemed "filed" with the SEC.)
41
21.3 - List of Subsidiaries of the Registrant at December 31,
2002.
(A) 31.1 - Certification letter from chief executive officer, as
adopted pursuant to Section 302 of the Sarbanes-Oxley
Act.
(A) 31.2 - Certification letter from chief financial officer, as
adopted pursuant to Section 302 of the Sarbanes-Oxley
Act.
(A) 32 - Certification letter from chief executive officer and
chief financial officer, as adopted pursuant to Section
906 of the Sarbanes-Oxley Act.
(A) Provided herein in electronic format as an exhibit.
(B) - Pursuant to paragraph (b)(4)(iii)(A) of Item 601 of
Regulation S-K, TE has not filed as an exhibit to this
Form 10-K any instrument with respect to long-term debt
if the total amount of securities authorized thereunder
does not exceed 10% of the total assets of TE, but
hereby agrees to furnish to the Commission on request
any such instruments.
(B) REPORTS ON FORM 8-K
FIRSTENERGY-
FirstEnergy filed twenty-four reports on Form 8-K since September 30,
2002. A report dated October 7, 2002 reported updated cost and schedule
estimates associated with efforts to return Davis-Besse Nuclear Power Station to
service. A report dated October 31, 2002 reported updated information associated
with Davis-Besse restoration efforts. A report dated December 2, 2002 reported
the merger of the GPU Employees Savings Plan into the FirstEnergy System Savings
Plan. A report dated December 3, 2002 reported updated FirstEnergy 2003 earnings
guidance. A report dated December 20, 2002 reported that FirstEnergy
subsidiaries would retain ownership of four power plants previously planned to
be sold. A report dated January 17, 2003 reported updated information related
with efforts to prepare Davis-Besse for a safe and reliable return to service
and the updated schedule for JCP&L rate proceedings. A report dated January 21,
2003 reported that the Pennsylvania Supreme Court denied further appeals of the
February 21, 2002 Pennsylvania Commonwealth Court decision, which effectively
affirmed the Pennsylvania Public Utility Commission's order approving the
FirstEnergy and GPU merger, let stand the Commonwealth Court's denial of PLR
relief for Met-Ed and Penelec and remanded the merger savings issue back to the
PPUC. A report dated March 11, 2003 reported updated Davis-Besse information
including the installation of the new reactor head on the reactor vessel. A
report dated March 17, 2003 reported updated Davis-Besse information, the filing
of a $2 billion shelf registration with the SEC and the status of the JCP&L rate
proceedings. A report dated March 18, 2003 reported NJBPU audit results of JCP&L
restructuring-related deferrals. A report dated April 16, 2003 reported updated
Davis-Besse information. A report dated April 18, 2003 reported FirstEnergy's
divestiture of its Argentina operations through the abandonment of its
investment resulting in a second quarter 2003 charge to net income of $63
million. A report dated May 1, 2003 reported FirstEnergy's first quarter 2003
results and other updated information including Davis-Besse updated ready for
restart schedule. A report dated May 9, 2003 reported updated Davis-Besse
information and a JCP&L rate proceedings update. A report dated May 9, 2003,
reported the filing of the Form 10-K/A Amendment No. 1. A report dated May 22,
2003, reported an agreement to sell FirstEnergy's 20.1% interest in United
Kingdom-based Aquila Sterling Limited, the owner of Midlands Electricity. A
report dated June 5, 2003 reported updated Davis-Besse information. A report
dated June 11, 2003, reported a letter filed with a Pennsylvania Public Utility
Commission Administrative Law Judge which voids a prior stipulation. A report
dated June 27, 2003, reported JCP&L's signing of a settlement agreement with
certain parties in its base rate case proceeding. A report dated July 24, 2003,
reported updates to the schedule and cost estimates for Davis-Besse. A reported
dated July 25, 2003 reported the New Jersey Board of Public Utilities decision
on JCP&L's rate proceedings. A report dated August 5, 2003 reported
FirstEnergy's second quarter 2003 earnings results and other information. A
report dated August 5, 2003 reported the pending restatement of 2002 FE, OE, CEI
and TE financial statements and restatement and reaudit of 2001 CEI and TE
financial statements. A report dated August 7, 2003 reported the pending
restatement and reaudit of 2000 CEI and TE financial statements. A report dated
August 8, 2003 reported a U.S. District Court ruling with respect to the W. H.
Sammis Plant under the Clean Air Act.
OE
OE filed two reports on Form 8-K since March 31, 2003. A report
dated August 5, 2003 reported the pending restatement of 2002 FE, OE, CEI and TE
financial statements. A report dated August 8, 2003 reported a U.S. District
Court ruling with respect to the W. H. Sammis Plant under the Clean Air Act.
None.
42
CEI
CEI filed thirteen reports on Form 8-K since September 30, 2002. A
report dated October 7, 2002 reported updated cost and schedule estimates
associated with efforts to return Davis-Besse Nuclear Power Station to service.
A report dated October 31, 2002 reported updated information associated with
Davis-Besse restoration efforts. A report dated December 20, 2002 reported that
FirstEnergy subsidiaries would retain ownership of four power plants previously
planned to be sold. A report dated January 17, 2003 reported updated information
related with efforts to prepare Davis-Besse for a safe and reliable return to
service. A report dated March 11, 2003 reported updated Davis-Besse information
including the installation of the new reactor head on the reactor vessel. A
report dated March 17, 2003 reported updated Davis-Besse information. A report
dated April 16, 2003 reported updated Davis-Besse information. A report dated
May 1, 2003 reported FirstEnergy's first quarter 2003 results and other updated
information including Davis-Besse updated ready for restart schedule. A report
dated May 9, 2003 reported updated Davis-Besse information. A report dated June
5, 2003 reported updated Davis Besse information. A report dated July 24, 2003,
reported updates to the schedule and cost estimates for Davis Besse. A report
dated August 5, 2003 reported the pending restatement of 2002 FE, OE, CEI and TE
financial statements and restatement and reaudit of 2001 CEI and TE financial
statements. A report dated August 7, 2003 reported the pending restatement and
reaudit of 2000 CEI and TE financial statements.
TE
TE filed thirteen reports on Form 8-K since September 30, 2002. A
report dated October 7, 2002 reported updated cost and schedule estimates
associated with efforts to return Davis-Besse Nuclear Power Station to service.
A report dated October 31, 2002 reported updated information associated with
Davis-Besse restoration efforts. A report dated December 20, 2002 reported that
FirstEnergy subsidiaries would retain ownership of four power plants previously
planned to be sold. A report dated January 17, 2003 reported updated information
related with efforts to prepare Davis-Besse for a safe and reliable return to
service. A report dated March 11, 2003 reported updated Davis-Besse information
including the installation of the new reactor head on the reactor vessel. A
report dated March 17, 2003 reported updated Davis-Besse information. A report
dated April 16, 2003 reported updated Davis-Besse information. A report dated
May 1, 2003 reported FirstEnergy's first quarter 2003 results and other updated
information including Davis-Besse updated ready for restart schedule. A report
dated May 9, 2003 reported updated Davis-Besse information. A report dated June
5, 2003 reported updated Davis Besse information. A report dated July 24, 2003,
reported updates to the schedule and cost estimates for Davis Besse. A report
dated August 5, 2003 reported the pending restatement of 2002 FE, OE, CEI and TE
financial statements and restatement and reaudit of 2001 CEI and TE financial
statements. A report dated August 7, 2003 reported the pending restatement and
reaudit of 2000 CEI and TE financial statements.
43
REPORT OF INDEPENDENT AUDITORS ON
FINANCIAL STATEMENT SCHEDULES
To the Stockholders and Board of Directors of
The Cleveland Electric Illuminating Company:
Our audits of the consolidated financial statements referred to in our report
dated August 18, 2003 appearing in the restated 2002 Annual Report to
Shareholders of The Cleveland Electric Illuminating Company (which report and
consolidated financial statements are incorporated by reference in this Form
10-K/A) also included an audit of the financial statement schedules listed in
Item 15(a)(2) of this Form 10-K/A. In our opinion, these financial statement
schedules present fairly, in all material respects, the information set forth
therein when read in conjunction with the related consolidated financial
statements.
PricewaterhouseCoopers LLP
Cleveland, Ohio
August 18, 2003
44
REPORT OF INDEPENDENT AUDITORS ON
FINANCIAL STATEMENT SCHEDULES
To the Stockholders and Board of Directors of
The Toledo Edison Company:
Our audits of the consolidated financial statements referred to in our report
dated August 18, 2003 appearing in the restated 2002 Annual Report to
Shareholders of The Toledo Edison Company (which report and consolidated
financial statements are incorporated by reference in this Form 10-K/A) also
included an audit of the financial statement schedules listed in Item 15(a)(2)
of this Form 10-K/A. In our opinion, these financial statement schedules present
fairly, in all material respects, the information set forth therein when read in
conjunction with the related consolidated financial statements.
PricewaterhouseCoopers LLP
Cleveland, Ohio
August 18, 2003
45
SCHEDULE II
THE CLEVELAND ELECTRIC ILLUMINATING COMPANY
CONSOLIDATED VALUATION AND QUALIFYING ACCOUNTS
FOR THE YEARS ENDED DECEMBER 31, 2002, 2001 AND 2000
ADDITIONS
--------------------
CHARGED
BEGINNING CHARGED TO OTHER ENDING
DESCRIPTION BALANCE TO INCOME ACCOUNTS DEDUCTIONS BALANCE
----------- --------- --------- -------- ---------- -------
(IN THOUSANDS)
YEAR ENDED DECEMBER 31, 2002:
Accumulated provision for
uncollectible accounts.................. $1,015 $ -- $ -- $ -- $1,015
====== ======== ====== ====== ======
YEAR ENDED DECEMBER 31, 2001:
Accumulated provision for
uncollectible accounts.................. $1,000 $ 15 $ -- $ -- $1,015
====== ======== ====== ====== ======
YEAR ENDED DECEMBER 31, 2000:
Accumulated provision for
uncollectible accounts.................. $1,000 $ -- $ -- $ -- $1,000
====== ========= ====== ====== ======
47
SCHEDULE II
THE TOLEDO EDISON COMPANY
CONSOLIDATED VALUATION AND QUALIFYING ACCOUNTS
FOR THE YEARS ENDED DECEMBER 31, 2002, 2001 AND 2000
ADDITIONS
--------------------
CHARGED
BEGINNING CHARGED TO OTHER ENDING
DESCRIPTION BALANCE TO INCOME ACCOUNTS DEDUCTIONS BALANCE
----------- --------- --------- -------- ---------- -------
(IN THOUSANDS)
YEAR ENDED DECEMBER 31, 2002:
Accumulated provision for
uncollectible accounts.................. $ 2 $ -- $ -- $ -- $ 2
========= ========= ========= ========= =========
YEAR ENDED DECEMBER 31, 2001:
Accumulated provision for
uncollectible accounts.................. $ -- $ 2 $ -- $ -- $ 2
========= ========= ========= ========= =========
YEAR ENDED DECEMBER 31, 2000:
Accumulated provision for
uncollectible accounts.................. $ -- $ -- $ -- $ -- $ --
========= ========= ========= ========= =========
48
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) 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.
FIRSTENERGY CORP.
Registrant
OHIO EDISON COMPANY
Registrant
THE CLEVELAND ELECTRIC
ILLUMINATING COMPANY
Registrant
THE TOLEDO EDISON COMPANY
Registrant
/s/Harvey L. Wagner
---------------------------------------
Harvey L. Wagner
Vice President, Controller
and Chief Accounting Officer
Date: August 18, 2003
49