q108_main10-qamended.htm
 


 
 

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

FORM 10-Q/A

Amendment No. 1

(Mark One)
[X]  QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2008

OR

[  ]  TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934

For the transition period from
 
to
 

Commission
Registrant; State of Incorporation;
I.R.S. Employer
File Number
Address; and Telephone Number
Identification No.
     
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
 
     
1-3522
PENNSYLVANIA ELECTRIC COMPANY
25-0718085
 
(A Pennsylvania Corporation)
 
 
c/o FirstEnergy Corp.
 
 
76 South Main Street
 
 
Akron, OH  44308
 
 
Telephone (800)736-3402
 



 
 

 

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 (  )
Ohio Edison Company and Pennsylvania Electric Company
Yes (  )  No (X)
The Cleveland Electric Illuminating Company and The Toledo Edison Company

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

Large Accelerated Filer
(  )
 
N/A
Accelerated Filer
(  )
 
N/A
Non-accelerated Filer (Do not check if a smaller reporting company)
(X)
Ohio Edison Company, The Cleveland Electric Illuminating Company, The Toledo Edison Company and Pennsylvania Electric Company

Smaller Reporting Company
(  )
N/A

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act).

Yes (  ) No (X)
Ohio Edison Company, The Cleveland Electric Illuminating Company, The Toledo Edison Company and Pennsylvania Electric Company

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date:

 
OUTSTANDING
CLASS
AS OF MAY 8, 2008
Ohio Edison Company, no par value
60
The Cleveland Electric Illuminating Company, no par value
67,930,743
The Toledo Edison Company, $5 par value
29,402,054
Pennsylvania Electric Company, $20 par value
4,427,577

This combined Form 10-Q/A is separately filed by Ohio Edison Company, The Cleveland Electric Illuminating Company, The Toledo Edison Company and Pennsylvania Electric Company. Information contained herein relating to any individual registrant is filed by such registrant on its own behalf.

OMISSION OF CERTAIN INFORMATION

Ohio Edison Company, The Cleveland Electric Illuminating Company, The Toledo Edison Company and Pennsylvania Electric Company meet the conditions set forth in General Instruction H(1)(a) and (b) of Form 10-Q and are therefore filing this Form 10-Q/A with the reduced disclosure format specified in General Instruction H(2) to Form 10-Q.

 
 

 

Forward-Looking Statements: This Form 10-Q/A includes forward-looking statements based on information currently available to management. Such statements are subject to certain risks and uncertainties. These statements include declarations regarding management’s intents, beliefs and current expectations. These statements typically contain, but are not limited to, the terms “anticipate,” “potential,” “expect,” “believe,” “estimate” and similar words. Forward-looking statements involve estimates, assumptions, known and unknown risks, uncertainties and other factors that may cause actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements.

Actual results may differ materially due to:
·  
the speed and nature of increased competition in the electric utility industry and legislative and regulatory changes affecting how generation rates will be determined following the expiration of existing rate plans in Ohio and Pennsylvania,
·  
the impact of the PUCO’s rulemaking process on the Ohio Companies’ ESP and MRO filings,
·  
economic or weather conditions affecting future sales and margins,
·  
changes in markets for energy services,
·  
changing energy and commodity market prices and availability,
·  
replacement power costs being higher than anticipated or inadequately hedged,
·  
the continued ability of FirstEnergy’s regulated utilities to collect transition and other charges or to recover increased transmission costs,
·  
maintenance costs being higher than anticipated,
·  
other legislative and regulatory changes, revised environmental requirements, including possible GHG emission regulations,
·  
the impact of the U.S. Court of Appeals’ July 11, 2008 decision to vacate the CAIR rules and the scope of any laws, rules or regulations that may ultimately take their place,
·  
the uncertainty of the timing and amounts of the capital expenditures needed to, among other things, implement the Air Quality Compliance Plan (including that such amounts could be higher than anticipated) or levels of emission reductions related to the Consent Decree resolving the NSR litigation or other potential regulatory initiatives,
·  
adverse regulatory or legal decisions and outcomes (including, but not limited to, the revocation of necessary licenses or operating permits and oversight) by the NRC (including, but not limited to, the Demand for Information issued to FENOC on May 14, 2007),
·  
the timing and outcome of various proceedings before the PUCO (including, but not limited to, the ESP and MRO proceedings as well as the distribution rate cases and the generation supply plan filing for the Ohio Companies and the successful resolution of the issues remanded to the PUCO by the Ohio Supreme Court regarding the RSP and RCP, including the recovery of deferred fuel costs),
·  
Met-Ed’s and Penelec’s transmission service charge filings with the PPUC as well as the resolution of the Petitions for Review filed with the Commonwealth Court of Pennsylvania with respect to the transition rate plan for Met-Ed and Penelec,
·  
the continuing availability of generating units and their ability to operate at or near full capacity,
·  
the ability to comply with applicable state and federal reliability standards,
·  
the ability to accomplish or realize anticipated benefits from strategic goals (including employee workforce initiatives),
·  
the ability to improve electric commodity margins and to experience growth in the distribution business,
·  
the changing market conditions that could affect the value of assets held in the registrants’ nuclear decommissioning trusts, pension trusts and other trust funds, and cause FirstEnergy to make additional contributions sooner, or in an amount that is larger than currently anticipated,
·  
the ability to access the public securities and other capital and credit markets in accordance with FirstEnergy’s financing plan and the cost of such capital,
·  
changes in general economic conditions affecting the registrants,
·  
the state of the capital and credit markets affecting the registrants, and
·  
the risks and other factors discussed from time to time in the registrants’ SEC filings, and other similar factors.

The foregoing review of factors should not be construed as exhaustive. New factors emerge from time to time, and it is not possible for management to predict all such factors, nor assess the impact of any such factor on the registrants’ business or the extent to which any factor, or combination of factors, may cause results to differ materially from those contained in any forward-looking statements. Also, a security rating is not a recommendation to buy, sell or hold securities, and it may be subject to revision or withdrawal at any time and each such rating should be evaluated independently of any other rating. The registrants expressly disclaim any current intention to update any forward-looking statements contained herein as a result of new information, future events or otherwise.



 
 

 



EXPLANATORY NOTE

This combined Amendment No. 1 on Form 10-Q/A for the quarter ended March 31, 2008 is being filed by Ohio Edison Company, The Cleveland Electric Illuminating Company, The Toledo Edison Company and Pennsylvania Electric Company (the “registrants”) to correct common stock dividend payments reported in their respective consolidated statements of cash flows for the three months ended March 31, 2008, contained in Part I, Item 1, Consolidated Financial Statements. This correction does not affect the respective registrants’ previously reported consolidated statements of income and comprehensive income for the three months ended March 31, 2008 and consolidated balance sheets as of March 31, 2008 contained in the combined Form 10-Q for the quarter ended March 31, 2008, as originally filed on May 8, 2008 (the “original Form 10-Q”). Except for Part I, Items 1 and 4T and certain exhibits under Part II, Item 6, no other information included in the Form 10-Q as originally filed is being revised by, or repeated in this amendment.

As discussed under “Restatement of the Consolidated Statements of Cash Flows” in Note 1 to the revised Combined Notes Consolidated Financial Statements of the registrants included in the Form 10-Q/A, the registrants have restated their respective consolidated statements of cash flows to correct common stock dividend payments reported in cash flows from financing activities. The consolidated statements of cash flows for those registrants, as originally filed, erroneously did not reflect the payment of common stock dividends in the first quarter of 2008, which were declared in the third quarter of 2007. The corrections resulted in a corresponding change in operating liabilities - accounts payable, included in cash flows from operating activities.

The original Form 10-Q was a combined Form 10-Q representing separate filings by each of the registrants and their affiliates, FirstEnergy Corp., FirstEnergy Solutions Corp., Jersey Central Power & Light Company, Metropolitan Edison Company (the “affiliates”). However, this Form 10-Q/A constitutes an amendment only to Part I, Items 1 and 4T and Part II, Item 6 of the Original Form 10-Q filed by each registrant. In addition, information contained herein relating to any individual registrant is filed by such registrant on its own behalf and no registrant makes any representation as to information contained herein relating to any other registrant or any of the affiliates, including, but not limited to, any such information contained in the revised Combined Notes to Consolidated Financial Statements included herein.

Please note that the information contained in this Amendment No. 1, including the consolidated financial statements and notes thereto, does not reflect events occurring after the date of the original Form 10-Q filing on May 8, 2008, except to the extent described above.


 

 
 

 

TABLE OF CONTENTS



   
Pages
Glossary of Terms
ii-iv
     
Part I.     Financial Information
 
     
Item 1. Financial Statements.
1
     
Ohio Edison Company
 
     
 
Report of Independent Registered Public Accounting Firm
2
 
Consolidated Statements of Income and Comprehensive Income
3
 
Consolidated Balance Sheets
4
 
Consolidated Statements of Cash Flows
5
     
The Cleveland Electric Illuminating Company
 
     
 
Report of Independent Registered Public Accounting Firm
6
 
Consolidated Statements of Income and Comprehensive Income
7
 
Consolidated Balance Sheets
8
 
Consolidated Statements of Cash Flows
9
     
The Toledo Edison Company
 
     
 
Report of Independent Registered Public Accounting Firm
10
 
Consolidated Statements of Income and Comprehensive Income
11
 
Consolidated Balance Sheets
12
 
Consolidated Statements of Cash Flows
13
     
Pennsylvania Electric Company
 
     
 
Report of Independent Registered Public Accounting Firm
14
 
Consolidated Statements of Income and Comprehensive Income
15
 
Consolidated Balance Sheets
16
 
Consolidated Statements of Cash Flows
17
   
Combined Notes to Consolidated Financial Statements
18-50
   
Item 4T.   Controls and Procedures – OE, CEI, TE and Penelec.
51
     
Part II.    Other Information
 
     
Item 6.     Exhibits.
52





 
i

 

GLOSSARY OF TERMS


The following abbreviations and acronyms are used in this report to identify FirstEnergy Corp. and its current and former subsidiaries:

ATSI
American Transmission Systems, Inc., owns and operates transmission facilities
 
CEI
The Cleveland Electric Illuminating Company, an Ohio electric utility operating subsidiary
 
Companies
OE, CEI, TE, JCP&L, Met-Ed and Penelec
 
FENOC
FirstEnergy Nuclear Operating Company, operates nuclear generating facilities
 
FES
FirstEnergy Solutions Corp., provides energy-related products and services
 
FESC
FirstEnergy Service Company, provides legal, financial and other corporate support services
 
FGCO
FirstEnergy Generation Corp., owns and operates non-nuclear generating facilities
 
FirstEnergy
FirstEnergy Corp., a public utility holding company
 
GPU
GPU, Inc., former parent of JCP&L, Met-Ed and Penelec, which merged with FirstEnergy on
November 7, 2001
 
JCP&L
Jersey Central Power & Light Company, a New Jersey electric utility operating subsidiary
 
JCP&L Transition
   Funding
JCP&L Transition Funding LLC, a Delaware limited liability company and issuer of transition
    bonds
 
JCP&L Transition
   Funding II
JCP&L Transition Funding II LLC, a Delaware limited liability company and issuer of transition bonds
 
Met-Ed
Metropolitan Edison Company, a Pennsylvania electric utility operating subsidiary
 
NGC
FirstEnergy Nuclear Generation Corp., owns nuclear generating facilities
 
OE
Ohio Edison Company, an Ohio electric utility operating subsidiary
 
Ohio Companies
CEI, OE and TE
 
Penelec
Pennsylvania Electric Company, a Pennsylvania electric utility operating subsidiary
 
Penn
Pennsylvania Power Company, a Pennsylvania electric utility operating subsidiary of OE
 
Pennsylvania Companies
Met-Ed, Penelec and Penn
 
PNBV
PNBV Capital Trust, a special purpose entity created by OE in 1996
 
Shippingport
Shippingport Capital Trust, a special purpose entity created by CEI and TE in 1997
 
TE
The Toledo Edison Company, an Ohio electric utility operating subsidiary
 
TEBSA
Termobarranquila S.A. Empresa de Servicios Publicos
 
     
The following abbreviations and acronyms are used to identify frequently used terms in this report:
 
     
AEP
American Electric Power Company, Inc.
 
AOCL
Accumulated Other Comprehensive Loss
 
AQC
Air Quality Control
 
ARB
Accounting Research Bulletin
 
ARO
Asset Retirement Obligation
 
ASM
Ancillary Services Market
 
BGS
Basic Generation Service
 
BPJ
Best Professional Judgment
 
CAA
Clean Air Act
 
CAIR
Clean Air Interstate Rule
 
CAMR
Clean Air Mercury Rule
 
CBP
Competitive Bid Process
 
CO2
Carbon Dioxide
 
DFI
Demand for Information
DOJ
United States Department of Justice
DRA
Division of Ratepayer Advocate
EIS
Energy Independence Strategy
EITF
Emerging Issues Task Force
EMP
Energy Master Plan
EPA
United States Environmental Protection Agency
EPACT
Energy Policy Act of 2005
ESP
Electric Security Plan
FASB
Financial Accounting Standards Board
FERC
Federal Energy Regulatory Commission
FIN
FASB Interpretation
FIN 46R
FIN 46 (revised December 2003), "Consolidation of Variable Interest Entities"

 
ii

 

GLOSSARY OF TERMS, Cont’d.


FIN 47
FIN 47, "Accounting for Conditional Asset Retirement Obligations - an interpretation of FASB
    Statement No. 143"
FIN 48
FIN 48, “Accounting for Uncertainty in Income Taxes - an interpretation of FASB Statement
    No. 109”
FirstCom
First Communications, Inc.
FMB
First Mortgage Bonds
FSP
FASB Staff Position
FSP FAS 157-2
FSP FAS 157-2, “Effective Date of  FASB Statement No. 157”
FTR
Financial Transmission Rights
GAAP
Accounting Principles Generally Accepted in the United States
GHG
Greenhouse Gases
ICE
Intercontinental Exchange
IRS
Internal Revenue Service
ISO
Independent System Operator
kV
Kilovolt
KWH
Kilowatt-hours
LIBOR
London Interbank Offered Rate
LOC
Letter of Credit
MEIUG
Met-Ed Industrial Users Group
MISO
Midwest Independent Transmission System Operator, Inc.
Moody’s
Moody’s Investors Service
MRO
Market Rate Offer
MW
Megawatts
NAAQS
National Ambient Air Quality Standards
NERC
North American Electric Reliability Corporation
NJBPU
New Jersey Board of Public Utilities
NOPR
Notice of Proposed Rulemaking
NOV
Notice of Violation
NOX
Nitrogen Oxide
NRC
Nuclear Regulatory Commission
NSR
New Source Review
NUG
Non-Utility Generation
NUGC
Non-Utility Generation Charge
NYMEX
New York Mercantile Exchange
OCA
Office of Consumer Advocate
OTC
Over the Counter
OVEC
Ohio Valley Electric Corporation
PCRB
Pollution Control Revenue Bond
PICA
Penelec Industrial Customer Alliance
PJM
PJM Interconnection L. L. C.
PLR
Provider of Last Resort
PPUC
Pennsylvania Public Utility Commission
PRP
Potentially Responsible Party
PSA
Power Supply Agreement
PUCO
Public Utilities Commission of Ohio
PUHCA
Public Utility Holding Company Act of 1935
RCP
Rate Certainty Plan
 
RECB
Regional Expansion Criteria and Benefits
 
RFP
Request for Proposal
 
RPM
Reliability Pricing Model
 
RSP
Rate Stabilization Plan
 
RTO
Regional Transmission Organization
 
S&P
Standard & Poor’s Ratings Service
 
SBC
Societal Benefits Charge
 
SEC
U.S. Securities and Exchange Commission
 
SECA
Seams Elimination Cost Adjustment
 
SFAS
Statement of Financial Accounting Standards
 
SFAS 109
SFAS No. 109, “Accounting for Income Taxes”
 
SFAS 123(R)
SFAS No. 123(R), "Share-Based Payment"
 
SFAS 133
SFAS No. 133, “Accounting for Derivative Instruments and Hedging Activities”
 

 
iii

 

GLOSSARY OF TERMS, Cont’d.


SFAS 141(R)
SFAS No 141(R), “Business Combinations”
SFAS 143
SFAS No. 143, “Accounting for Asset Retirement Obligations”
SFAS 157
SFAS No. 157, “Fair Value Measurements”
SFAS 159
SFAS No. 159, “The Fair Value Option for Financial Assets and Financial Liabilities – Including an
    Amendment of FASB Statement No. 115”
SFAS 160
SFAS No. 160, “Noncontrolling Interests in Consolidated Financial Statements – an Amendment
   of ARB No. 51”
SFAS 161
SFAS No 161, “Disclosure about Derivative Instruments and Hedging Activities – an Amendment
    of FASB Statement No. 133”
SIP
State Implementation Plan(s) Under the Clean Air Act
SNCR
Selective Non-Catalytic Reduction
SO2
Sulfur Dioxide
TBC
Transition Bond Charge
TMI-1
Three Mile Island Unit 1
TMI-2
Three Mile Island Unit 2
TSC
Transmission Service Charge
VIE
Variable Interest Entity

 
iv

 

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS.



 
1

 

 
Report of Independent Registered Public Accounting Firm










To the Stockholder and Board of
Directors of Ohio Edison Company:

We have reviewed the accompanying consolidated balance sheet of Ohio Edison Company and its subsidiaries as of March 31, 2008 and the related consolidated statements of income, comprehensive income and cash flows for each of the three-month periods ended March 31, 2008 and 2007. These interim financial statements are the responsibility of the Company’s management.

We conducted our review in accordance with the standards of the Public Company Accounting Oversight Board (United States). A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the Public Company Accounting Oversight Board (United States), the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

Based on our review, we are not aware of any material modifications that should be made to the accompanying consolidated interim financial statements for them to be in conformity with accounting principles generally accepted in the United States of America.

We previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet as of December 31, 2007, and the related consolidated statements of income, capitalization, common stockholders’ equity, and cash flows for the year then ended (not presented herein), and in our report dated February 28, 2008, except as to the error correction described in Note 1, which is as of November 24, 2008, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying consolidated balance sheet information as of December 31, 2007, is fairly stated in all material respects in relation to the consolidated balance sheet from which it has been derived.

As discussed in Note 1 to the consolidated financial statements, the Company has restated its 2008 financial statements to correct an error.

 
PricewaterhouseCoopers LLP
Cleveland, Ohio
May 7, 2008, except as to the error correction described in Note 1,
which is as of November 24, 2008.
 





 
2

 


 
OHIO EDISON COMPANY
 
             
CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME
 
(Unaudited)
 
             
   
Three Months Ended
 
   
March 31,
 
             
   
2008
   
2007
 
   
(In thousands)
 
             
REVENUES:
           
Electric sales
  $ 622,271     $ 594,344  
Excise tax collections
    30,378       31,254  
Total revenues
    652,649       625,598  
                 
EXPENSES:
               
Fuel
    3,170       3,015  
Purchased power
    340,186       349,852  
Nuclear operating costs
    43,021       41,514  
Other operating costs
    94,135       88,486  
Provision for depreciation
    21,493       18,848  
Amortization of regulatory assets
    48,538       45,417  
Deferral of new regulatory assets
    (25,411 )     (36,649 )
General taxes
    50,453       49,745  
Total expenses
    575,585       560,228  
                 
OPERATING INCOME
    77,064       65,370  
                 
OTHER INCOME (EXPENSE):
               
Investment income
    15,055       26,630  
Miscellaneous income (expense)
    (3,806 )     373  
Interest expense
    (17,641 )     (21,022 )
Capitalized interest
    110       110  
Total other income (expense)
    (6,282 )     6,091  
                 
INCOME BEFORE INCOME TAXES
    70,782       71,461  
                 
INCOME TAXES
    26,873       17,426  
                 
NET INCOME
    43,909       54,035  
                 
OTHER COMPREHENSIVE INCOME (LOSS):
               
Pension and other postretirement benefits
    (3,994 )     (3,423 )
Change in unrealized gain on available-for-sale securities
    (7,571 )     (126 )
Other comprehensive loss
    (11,565 )     (3,549 )
Income tax benefit related to other comprehensive loss
    (4,262 )     (1,503 )
Other comprehensive loss, net of tax
    (7,303 )     (2,046 )
                 
TOTAL COMPREHENSIVE INCOME
  $ 36,606     $ 51,989  
                 
The accompanying Notes to Consolidated Financial Statements as they relate to Ohio Edison Company are an integral part
 
of these statements.
               

 
3

 


OHIO EDISON COMPANY
 
             
CONSOLIDATED BALANCE SHEETS
 
(Unaudited)
 
   
March 31,
   
December 31,
 
   
2008
   
2007
 
   
  (In thousands)
 
ASSETS
           
CURRENT ASSETS:
           
Cash and cash equivalents
  $ 732     $ 732  
Receivables-
               
Customers (less accumulated provisions of $7,870,000 and $8,032,000,
               
respectively, for uncollectible accounts)
    266,360       248,990  
Associated companies
    179,875       185,437  
Other (less accumulated provisions of $5,638,000 and $5,639,000,
               
respectively, for uncollectible accounts)
    16,474       12,395  
Notes receivable from associated companies
    589,790       595,859  
Prepayments and other
    17,785       10,341  
      1,071,016       1,053,754  
UTILITY PLANT:
               
In service
    2,804,505       2,769,880  
Less - Accumulated provision for depreciation
    1,106,174       1,090,862  
      1,698,331       1,679,018  
Construction work in progress
    60,617       50,061  
      1,758,948       1,729,079  
OTHER PROPERTY AND INVESTMENTS:
               
Long-term notes receivable from associated companies
    258,405       258,870  
Investment in lease obligation bonds
    253,747       253,894  
Nuclear plant decommissioning trusts
    119,948       127,252  
Other
    33,014       36,037  
      665,114       676,053  
DEFERRED CHARGES AND OTHER ASSETS:
               
Regulatory assets
    709,969       737,326  
Pension assets
    235,933       228,518  
Property taxes
    65,520       65,520  
Unamortized sale and leaseback costs
    43,882       45,133  
Other
    44,640       48,075  
      1,099,944       1,124,572  
    $ 4,595,022     $ 4,583,458  
LIABILITIES AND CAPITALIZATION
               
CURRENT LIABILITIES:
               
Currently payable long-term debt
  $ 334,656     $ 333,224  
Short-term borrowings-
               
Associated companies
    50,692       50,692  
Other
    2,609       2,609  
Accounts payable-
               
Associated companies
    155,654       174,088  
Other
    19,376       19,881  
Accrued taxes
    93,390       89,571  
Accrued interest
    16,459       22,378  
Other
    99,532       65,163  
      772,368       757,606  
CAPITALIZATION:
               
Common stockholder's equity-
               
Common stock, without par value, authorized 175,000,000 shares -
               
60 shares outstanding
    1,220,368       1,220,512  
Accumulated other comprehensive income
    41,083       48,386  
Retained earnings
    351,186       307,277  
Total common stockholder's equity
    1,612,637       1,576,175  
Long-term debt and other long-term obligations
    839,107       840,591  
      2,451,744       2,416,766  
NONCURRENT LIABILITIES:
               
Accumulated deferred income taxes
    783,777       781,012  
Accumulated deferred investment tax credits
    15,990       16,964  
Asset retirement obligations
    95,009       93,571  
Retirement benefits
    176,597       178,343  
Deferred revenues - electric service programs
    36,821       46,849  
Other
    262,716       292,347  
      1,370,910       1,409,086  
COMMITMENTS AND CONTINGENCIES (Note 10)
               
    $ 4,595,022     $ 4,583,458  
                 
The accompanying Notes to Consolidated Financial Statements as they relate to Ohio Edison Company are an integral part
 
of these balance sheets.
               

 
4

 
 
OHIO EDISON COMPANY
 
CONSOLIDATED STATEMENTS OF CASH FLOWS
 
(Unaudited)
 
   
  Three Months Ended
 March 31,
 
   
Restated
       
   
2008
   
2007
 
   
(In thousands)
 
CASH FLOWS FROM OPERATING ACTIVITIES:
           
Net income
  $ 43,909     $ 54,035  
Adjustments to reconcile net income to net cash from operating activities-
               
Provision for depreciation
    21,493       18,848  
Amortization of regulatory assets
    48,538       45,417  
Deferral of new regulatory assets
    (25,411 )     (36,649 )
Amortization of lease costs
    32,934       32,934  
Deferred income taxes and investment tax credits, net
    6,866       (3,992 )
Accrued compensation and retirement benefits
    (19,482 )     (16,794 )
Pension trust contribution
    -       (20,261 )
Increase in operating assets-
               
Receivables
    (27,496 )     (102,469 )
Prepayments and other current assets
    (7,451 )     (6,339 )
Increase (decrease) in operating liabilities-
               
Accounts payable
    (3,939 )     42,095  
Accrued taxes
    2,991       (46,791 )
Accrued interest
    (5,919 )     (6,812 )
Electric service prepayment programs
    (10,028 )     (9,053 )
  Other
    (2,066 )     (3,283 )
Net cash provided from (used for) operating activities
    54,939       (59,114 )
                 
CASH FLOWS FROM FINANCING ACTIVITIES:
               
 New Financing-
               
Short-term borrowings, net
    -       77,473  
 Redemptions and Repayments-
               
Common stock
    -       (500,000 )
Long-term debt
    (80 )     (72 )
 Dividend Payments-
               
Common stock
    (15,000 )     -  
 Net cash used for financing activities
    (15,080 )     (422,599 )
                 
CASH FLOWS FROM INVESTING ACTIVITIES:
               
Property additions
    (49,011 )     (29,888 )
Sales of investment securities held in trusts
    62,344       12,951  
Purchases of investment securities held in trusts
    (63,797 )     (13,805 )
Loan repayments from associated companies, net
    6,534       511,082  
Cash investments
    147       168  
Other
    3,924       1,187  
Net cash provided from (used for) investing activities
    (39,859 )     481,695  
                 
Net change in cash and cash equivalents
    -       (18 )
Cash and cash equivalents at beginning of period
    732       712  
Cash and cash equivalents at end of period
  $ 732     $ 694  
                 
The accompanying Notes to Consolidated Financial Statements as they relate to Ohio Edison Company are an integral part
 
of these statements.
               
 
 
5


Report of Independent Registered Public Accounting Firm









To the Stockholder and Board of Directors of
The Cleveland Electric Illuminating Company:

We have reviewed the accompanying consolidated balance sheet of The Cleveland Electric Illuminating Company and its subsidiaries as of March 31, 2008 and the related consolidated statements of income, comprehensive income and cash flows for each of the three-month periods ended March 31, 2008 and 2007. These interim financial statements are the responsibility of the Company’s management.

We conducted our review in accordance with the standards of the Public Company Accounting Oversight Board (United States). A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the Public Company Accounting Oversight Board (United States), the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

Based on our review, we are not aware of any material modifications that should be made to the accompanying consolidated interim financial statements for them to be in conformity with accounting principles generally accepted in the United States of America.

We previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet as of December 31, 2007, and the related consolidated statements of income, capitalization, common stockholders’ equity, and cash flows for the year then ended (not presented herein), and in our report dated February 28, 2008, except as to the error correction described in Note 1, which is as of November 24, 2008, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying consolidated balance sheet information as of December 31, 2007, is fairly stated in all material respects in relation to the consolidated balance sheet from which it has been derived.

As discussed in Note 1 to the consolidated financial statements, the Company has restated its 2008 financial statements to correct an error.
 

 
PricewaterhouseCoopers LLP
Cleveland, Ohio
May 7, 2008, except as to the error correction described in Note 1,
which is as of November 24, 2008.

 
6

 


 
THE CLEVELAND ELECTRIC ILLUMINATING COMPANY
 
             
CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME
 
(Unaudited)
 
             
   
 Three Months Ended
 
   
 March 31,
 
             
   
2008
   
2007
 
   
 (In thousands)
 
             
REVENUES:
           
Electric sales
  $ 418,708     $ 422,805  
Excise tax collections
    18,600       18,027  
Total revenues
    437,308       440,832  
                 
EXPENSES:
               
Fuel
    -       13,191  
Purchased power
    193,244       180,657  
Other operating costs
    65,118       74,951  
Provision for depreciation
    19,076       18,468  
Amortization of regulatory assets
    38,256       33,129  
Deferral of new regulatory assets
    (29,248 )     (33,957 )
General taxes
    40,083       38,894  
Total expenses
    326,529       325,333  
                 
OPERATING INCOME
    110,779       115,499  
                 
OTHER INCOME (EXPENSE):
               
Investment income
    9,188       17,687  
Miscellaneous income
    534       731  
Interest expense
    (32,520 )     (35,740 )
Capitalized interest
    196       205  
Total other expense
    (22,602 )     (17,117 )
                 
INCOME BEFORE INCOME TAXES
    88,177       98,382  
                 
INCOME TAXES
    30,326       34,833  
                 
NET INCOME
    57,851       63,549  
                 
OTHER COMPREHENSIVE INCOME (LOSS):
               
Pension and other postretirement benefits
    (213 )     1,202  
Income tax expense related to other comprehensive income
    281       355  
Other comprehensive income (loss), net of tax
    (494 )     847  
                 
TOTAL COMPREHENSIVE INCOME
  $ 57,357     $ 64,396  
                 
The accompanying Notes to Consolidated Financial Statements as they relate to The Cleveland Electric Illuminating
 
Company are an integral part of these statements.
               

 
 
7

 

 
 
THE CLEVELAND ELECTRIC ILLUMINATING COMPANY
 
             
CONSOLIDATED BALANCE SHEETS
 
(Unaudited)
 
   
March 31,
   
December 31,
 
   
2008
   
2007
 
   
(In thousands)
 
ASSETS
           
CURRENT ASSETS:
           
Cash and cash equivalents
  $ 241     $ 232  
Receivables-
               
Customers (less accumulated provisions of $7,224,000 and $7,540,000,
    266,701       251,000  
respectively, for uncollectible accounts)
               
Associated companies
    70,727       166,587  
Other
    3,643       12,184  
Notes receivable from associated companies
    54,679       52,306  
Prepayments and other
    1,728       2,327  
      397,719       484,636  
UTILITY PLANT:
               
In service
    2,142,458       2,256,956  
Less - Accumulated provision for depreciation
    827,160       872,801  
      1,315,298       1,384,155  
Construction work in progress
    40,834       41,163  
      1,356,132       1,425,318  
OTHER PROPERTY AND INVESTMENTS:
               
Investment in lessor notes
    425,722       463,431  
Other
    10,275       10,285  
      435,997       473,716  
DEFERRED CHARGES AND OTHER ASSETS:
               
Goodwill
    1,688,521       1,688,521  
Regulatory assets
    853,716       870,695  
Pension assets
    64,497       62,471  
Property taxes
    76,000       76,000  
Other
    32,735       32,987  
      2,715,469       2,730,674  
    $ 4,905,317     $ 5,114,344  
LIABILITIES AND CAPITALIZATION
               
CURRENT LIABILITIES:
               
Currently payable long-term debt
  $ 207,281     $ 207,266  
Short-term borrowings-
               
Associated companies
    365,816       531,943  
Accounts payable-
               
Associated companies
    139,423       169,187  
Other
    6,169       5,295  
Accrued taxes
    118,102       94,991  
Accrued interest
    37,726       13,895  
Other
    35,044       34,350  
      909,561       1,056,927  
CAPITALIZATION:
               
Common stockholder's equity
               
Common stock, without par value, authorized 105,000,000 shares -
               
67,930,743 shares outstanding
    873,353       873,536  
Accumulated other comprehensive loss
    (69,623 )     (69,129 )
Retained earnings
    743,278       685,428  
Total common stockholder's equity
    1,547,008       1,489,835  
Long-term debt and other long-term obligations
    1,447,980       1,459,939  
      2,994,988       2,949,774  
NONCURRENT LIABILITIES:
               
Accumulated deferred income taxes
    719,938       725,523  
Accumulated deferred investment tax credits
    18,102       18,567  
Retirement benefits
    94,322       93,456  
Deferred revenues - electric service programs
    21,297       27,145  
Lease assignment payable to associated companies
    38,420       131,773  
Other
    108,689       111,179  
      1,000,768       1,107,643  
COMMITMENTS AND CONTINGENCIES (Note 10)
               
    $ 4,905,317     $ 5,114,344  
                 
The accompanying Notes to Consolidated Financial Statements as they relate to The Cleveland Electric Illuminating
 
Company are an integral part of these balance sheets.
               

 
8

 
 
THE CLEVELAND ELECTRIC ILLUMINATING COMPANY
 
CONSOLIDATED STATEMENTS OF CASH FLOWS
 
(Unaudited)
 
   
Three Months Ended
 
   
March 31,
 
   
Restated
       
   
2008
   
2007
 
   
(In thousands)
 
CASH FLOWS FROM OPERATING ACTIVITIES:
           
Net income
  $ 57,851     $ 63,549  
Adjustments to reconcile net income to net cash from operating activities-
               
Provision for depreciation
    19,076       18,468  
Amortization of regulatory assets
    38,256       33,129  
Deferral of new regulatory assets
    (29,248 )     (33,957 )
Deferred rents and lease market valuation liability
    -       (46,528 )
Deferred income taxes and investment tax credits, net
    (4,965 )     (5,453 )
Accrued compensation and retirement benefits
    (3,507 )     (890 )
Pension trust contribution
    -       (24,800 )
Decrease in operating assets-
               
Receivables
    90,280       224,011  
Prepayments and other current assets
    604       592  
Increase (decrease) in operating liabilities-
               
Accounts payable
    1,111       (256,808 )
Accrued taxes
    23,196       13,959  
Accrued interest
    23,831       18,122  
Electric service prepayment programs
    (5,847 )     (5,313 )
Other
    (63 )     (167 )
Net cash provided from (used for) operating activities
    210,575       (2,086 )
                 
CASH FLOWS FROM FINANCING ACTIVITIES:
               
New Financing-
               
Long-term debt
    -       247,715  
Redemptions and Repayments-
               
Long-term debt
    (165 )     (150 )
Short-term borrowings, net
    (177,960 )     (130,585 )
Dividend Payments-
               
Common stock
    (30,000 )     (24,000 )
Net cash provided from (used for) financing activities
    (208,125 )     92,980  
                 
CASH FLOWS FROM INVESTING ACTIVITIES:
               
Property additions
    (37,203 )     (36,682 )
Loans to associated companies, net
    (2,373 )     (231,907 )
Collection of principal on long-term notes receivable
    -       133,341  
Redemptions of lessor notes
    37,709       35,614  
Other
    (574 )     9,294  
Net cash used for investing activities
    (2,441 )     (90,340 )
                 
Net increase in cash and cash equivalents
    9       554  
Cash and cash equivalents at beginning of period
    232       221  
Cash and cash equivalents at end of period
  $ 241     $ 775  
                 
The accompanying Notes to Consolidated Financial Statements as they relate to The Cleveland Electric Illuminating
 
Company are an integral part of these statements.
               
 
 
9


 Report of Independent Registered Public Accounting Firm






 


 
To the Stockholder and Board of
Directors of The Toledo Edison Company:

We have reviewed the accompanying consolidated balance sheet of The Toledo Edison Company and its subsidiary as of March 31, 2008 and the related consolidated statements of income, comprehensive income and cash flows for each of the three-month periods ended March 31, 2008 and 2007. These interim financial statements are the responsibility of the Company’s management.

We conducted our review in accordance with the standards of the Public Company Accounting Oversight Board (United States). A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the Public Company Accounting Oversight Board (United States), the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

Based on our review, we are not aware of any material modifications that should be made to the accompanying consolidated interim financial statements for them to be in conformity with accounting principles generally accepted in the United States of America.

We previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet as of December 31, 2007, and the related consolidated statements of income, capitalization, common stockholders’ equity, and cash flows for the year then ended (not presented herein), and in our report dated February 28, 2008, except as to the error correction described in Note 1, which is as of November 24, 2008, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying consolidated balance sheet information as of December 31, 2007, is fairly stated in all material respects in relation to the consolidated balance sheet from which it has been derived.

As discussed in Note 1 to the consolidated financial statements, the Company has restated its 2008 financial statements to correct an error.

 
PricewaterhouseCoopers LLP
Cleveland, Ohio
May 7, 2008, except as to the error correction described in Note 1,
which is as of November 24, 2008.
 

 
 
10

 


 
THE TOLEDO EDISON COMPANY
 
             
CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME
 
(Unaudited)
 
             
   
Three Months Ended
 
   
March 31,
 
             
   
2008
   
2007
 
   
(In thousands)
 
             
REVENUES:
           
Electric sales
  $ 203,669     $ 233,056  
Excise tax collections
    8,025       7,400  
Total revenues
    211,694       240,456  
                 
EXPENSES:
               
Fuel
    1,482       10,147  
Purchased power
    101,298       96,169  
Nuclear operating costs
    10,457       17,721  
Other operating costs
    33,390       42,921  
Provision for depreciation
    9,025       9,117  
Amortization of regulatory assets
    25,025       23,876  
Deferral of new regulatory assets
    (9,494 )     (13,481 )
General taxes
    14,377       13,734  
Total expenses
    185,560       200,204  
                 
OPERATING INCOME
    26,134       40,252  
                 
OTHER INCOME (EXPENSE):
               
Investment income
    6,481       7,225  
Miscellaneous expense
    (1,514 )     (3,100 )
Interest expense
    (6,035 )     (7,503 )
Capitalized interest
    37       83  
Total other expense
    (1,031 )     (3,295 )
                 
INCOME BEFORE INCOME TAXES
    25,103       36,957  
                 
INCOME TAXES
    8,088       11,097  
                 
NET INCOME
    17,015       25,860  
                 
OTHER COMPREHENSIVE INCOME (LOSS):
               
Pension and other postretirement benefits
    (63 )     573  
Change in unrealized gain on available-for-sale securities
    1,961       379  
Other comprehensive income
    1,898       952  
Income tax expense related to other comprehensive income
    728       334  
Other comprehensive income, net of tax
    1,170       618  
                 
TOTAL COMPREHENSIVE INCOME
  $ 18,185     $ 26,478  
                 
The accompanying Notes to Consolidated Financial Statements as they relate to The Toledo Edison Company
 
are an integral part of these statements.
               

 
11

 


THE TOLEDO EDISON COMPANY
 
             
CONSOLIDATED BALANCE SHEETS
 
(Unaudited)
 
 
March 31,
   
December 31,
 
   
2008
   
2007
 
   
 (In thousands)
 
ASSETS
           
CURRENT ASSETS:
           
Cash and cash equivalents
  $ 213     $ 22  
Receivables-
               
Customers
    966       449  
Associated companies
    42,232       88,796  
Other (less accumulated provisions of $471,000 and $615,000,
         
respectively, for uncollectible accounts)
    4,241       3,116  
Notes receivable from associated companies
    107,664       154,380  
Prepayments and other
    684       865  
      156,000       247,628  
UTILITY PLANT:
               
In service
    854,457       931,263  
Less - Accumulated provision for depreciation
    397,670       420,445  
      456,787       510,818  
Construction work in progress
    28,735       19,740  
      485,522       530,558  
OTHER PROPERTY AND INVESTMENTS:
               
Investment in lessor notes
    142,657       154,646  
Long-term notes receivable from associated companies
    37,457       37,530  
Nuclear plant decommissioning trusts
    69,491       66,759  
Other
    1,734       1,756  
      251,339       260,691  
DEFERRED CHARGES AND OTHER ASSETS:
               
Goodwill
    500,576       500,576  
Regulatory assets
    187,579       203,719  
Pension assets
    29,420       28,601  
Property taxes
    21,010       21,010  
Other
    28,959       20,496  
      767,544       774,402  
    $ 1,660,405     $ 1,813,279  
LIABILITIES AND CAPITALIZATION
               
CURRENT LIABILITIES:
               
Currently payable long-term debt
  $ 34     $ 34  
Accounts payable-
               
Associated companies
    56,448       245,215  
Other
    3,973       4,449  
Notes payable to associated companies
    66,217       13,396  
Accrued taxes
    37,085       30,245  
Lease market valuation liability
    36,900       36,900  
Other
    51,563       22,747  
      252,220       352,986  
CAPITALIZATION:
               
Common stockholder's equity-
               
Common stock, $5 par value, authorized 60,000,000 shares -
         
29,402,054 shares outstanding
    147,010       147,010  
Other paid-in capital
    173,141       173,169  
Accumulated other comprehensive loss
    (9,436 )     (10,606 )
Retained earnings
    192,633       175,618  
Total common stockholder's equity
    503,348       485,191  
Long-term debt and other long-term obligations
    303,392       303,397  
      806,740       788,588  
NONCURRENT LIABILITIES:
               
Accumulated deferred income taxes
    99,732       103,463  
Accumulated deferred investment tax credits
    9,967       10,180  
Lease market valuation liability
    300,775       310,000  
Retirement benefits
    64,422       63,215  
Asset retirement obligations
    28,744       28,366  
Deferred revenues - electric service programs
    9,969       12,639  
Lease assignment payable to associated companies
    28,835       83,485  
Other
    59,001       60,357  
      601,445       671,705  
COMMITMENTS AND CONTINGENCIES (Note 10)
               
    $ 1,660,405     $ 1,813,279  
                 
The accompanying Notes to Consolidated Financial Statements as they relate to The Toledo Edison Company
 
are an integral part of these balance sheets.
               

 
12

 
 
THE TOLEDO EDISON COMPANY
 
CONSOLIDATED STATEMENTS OF CASH FLOWS
 
(Unaudited)
 
   
Three Months Ended
 
   
March 31,
 
   
Restated
       
   
2008
   
2007
 
   
(In thousands)
 
CASH FLOWS FROM OPERATING ACTIVITIES:
           
Net income
  $ 17,015     $ 25,860  
Adjustments to reconcile net income to net cash from operating activities-
               
Provision for depreciation
    9,025       9,117  
Amortization of regulatory assets
    25,025       23,876  
Deferral of new regulatory assets
    (9,494 )     (13,481 )
Deferred rents and lease market valuation liability
    6,099       (10,891 )
Deferred income taxes and investment tax credits, net
    (3,404 )     (3,639 )
Accrued compensation and retirement benefits
    (1,813 )     (756 )
Pension trust contribution
    -       (7,659 )
Decrease in operating assets-
               
Receivables
    45,738       158  
Prepayments and other current assets
    181       312  
Increase (decrease) in operating liabilities-
               
Accounts payable
    (174,243 )     (17,533 )
Accrued taxes
    6,840       9,379  
Accrued interest
    4,663       3,951  
Electric service prepayment programs
    (2,670 )     (2,616 )
Other
    991       (541 )
Net cash provided from (used for) operating activities
    (76,047 )     15,537  
                 
CASH FLOWS FROM FINANCING ACTIVITIES:
               
New Financing-
               
Short-term borrowings, net
    52,821       -  
Redemptions and Repayments-
               
Long-term debt
    (9 )     -  
Short-term borrowings, net
    -       (46,518 )
Dividend Payments-
               
Common stock
    (15,000 )     -  
Net cash provided from (used for) financing activities
    37,812       (46,518 )
                 
CASH FLOWS FROM INVESTING ACTIVITIES:
               
Property additions
    (19,435 )     (6,064 )
Loans repayments from (loans to) associated companies, net
    46,789       (8,583 )
Collection of principal on long-term notes receivable
    -       32,202  
Redemption of lessor notes
    11,989       14,804  
Sales of investment securities held in trusts
    3,908       16,863  
Purchases of investment securities held in trusts
    (4,715 )     (17,642 )
Other
    (110 )     (420 )
Net cash provided from investing activities
    38,426       31,160  
                 
Net increase in cash and cash equivalents
    191       179  
Cash and cash equivalents at beginning of period
    22       22  
Cash and cash equivalents at end of period
  $ 213     $ 201  
                 
The accompanying Notes to Consolidated Financial Statements as they relate to The Toledo Edison Company are an
         
integral part of these statements.
               
 

 
13

 

Report of Independent Registered Public Accounting Firm




 




 
To the Stockholder and Board of
Directors of Pennsylvania Electric Company:

We have reviewed the accompanying consolidated balance sheet of Pennsylvania Electric Company and its subsidiaries as of March 31, 2008 and the related consolidated statements of income, comprehensive income and cash flows for each of the three-month periods ended March 31, 2008 and 2007. These interim financial statements are the responsibility of the Company’s management.

We conducted our review in accordance with the standards of the Public Company Accounting Oversight Board (United States). A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the Public Company Accounting Oversight Board (United States), the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

Based on our review, we are not aware of any material modifications that should be made to the accompanying consolidated interim financial statements for them to be in conformity with accounting principles generally accepted in the United States of America.

We previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet as of December 31, 2007, and the related consolidated statements of income, capitalization, common stockholders’ equity, and cash flows for the year then ended (not presented herein), and in our report dated February 28, 2008, except as to the error correction described in Note 1, which is as of November 24, 2008, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying consolidated balance sheet information as of December 31, 2007, is fairly stated in all material respects in relation to the consolidated balance sheet from which it has been derived.

As discussed in Note 1 to the consolidated financial statements, the Company has restated its 2008 financial statements to correct an error.

 
PricewaterhouseCoopers LLP
Cleveland, Ohio
May 7, 2008, except as to the error correction described in Note 1,
which is as of November 24, 2008.

 
 
14

 


PENNSYLVANIA ELECTRIC COMPANY
 
             
CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME
 
(Unaudited)
 
             
 
Three Months Ended
 
 
March 31,
 
             
   
2008
   
2007
 
             
 
(In thousands)
 
             
REVENUES:
           
Electric sales
  $ 376,028     $ 339,226  
Gross receipts tax collections
    19,464       16,680  
Total revenues
    395,492       355,906  
                 
EXPENSES:
               
Purchased power
    221,234       200,842  
Other operating costs
    71,077       59,461  
Provision for depreciation
    12,516       11,777  
Amortization of regulatory assets
    16,346       15,394  
Deferral of new regulatory assets
    (3,526 )     (17,088 )
General taxes
    21,855       19,851  
Total expenses
    339,502       290,237  
                 
OPERATING INCOME
    55,990       65,669  
                 
OTHER INCOME (EXPENSE):
               
Miscellaneous income (expense)
    (191 )     1,417  
Interest expense
    (15,322 )     (11,337 )
Capitalized interest
    (806 )     258  
Total other expense
    (16,319 )     (9,662 )
                 
INCOME BEFORE INCOME TAXES
    39,671       56,007  
                 
INCOME TAXES
    18,279       24,263  
                 
NET INCOME
    21,392       31,744  
                 
OTHER COMPREHENSIVE INCOME (LOSS):
               
Pension and other postretirement benefits
    (3,473 )     (2,825 )
Unrealized gain on derivative hedges
    16       16  
Change in unrealized gain on available-for-sale securities
    11       (3 )
Other comprehensive loss
    (3,446 )     (2,812 )
Income tax benefit related to other comprehensive loss
    (1,506 )     (1,298 )
Other comprehensive loss, net of tax
    (1,940 )     (1,514 )
                 
TOTAL COMPREHENSIVE INCOME
  $ 19,452     $ 30,230  
                 
The accompanying Notes to Consolidated Financial Statements as they relate to Pennsylvania Electric Company
 
are an integral part of these statements.
               

 
15

 


PENNSYLVANIA ELECTRIC COMPANY
 
             
CONSOLIDATED BALANCE SHEETS
 
(Unaudited)
 
   
March 31,
   
December 31,
 
   
2008
   
2007
 
   
(In thousands)
 
ASSETS
           
CURRENT ASSETS:
           
Cash and cash equivalents
  $ 43     $ 46  
Receivables-
               
Customers (less accumulated provisions of $4,201,000 and $3,905,000,
               
respectively, for uncollectible accounts)
    141,316       137,455  
Associated companies
    23,396       22,014  
Other
    28,833       19,529  
Notes receivable from associated companies
    16,923       16,313  
Prepaid gross receipts taxes
    41,242       -  
Other
    2,426       3,077  
      254,179       198,434  
UTILITY PLANT:
               
In service
    2,230,667       2,219,002  
Less - Accumulated provision for depreciation
    843,500       838,621  
      1,387,167       1,380,381  
Construction work in progress
    33,727       24,251  
      1,420,894       1,404,632  
OTHER PROPERTY AND INVESTMENTS:
               
Nuclear plant decommissioning trusts
    132,152       137,859  
Non-utility generation trusts
    113,958       112,670  
Other
    536       531  
      246,646       251,060  
DEFERRED CHARGES AND OTHER ASSETS:
               
Goodwill
    777,616       777,904  
Pension assets
    69,405       66,111  
Other
    29,770       33,893  
      876,791       877,908  
    $ 2,798,510     $ 2,732,034  
LIABILITIES AND CAPITALIZATION
               
CURRENT LIABILITIES:
               
Short-term borrowings-
               
Associated companies
  $ 183,102     $ 214,893  
Other
    150,000       -  
Accounts payable-
               
Associated companies
    61,476       83,359  
Other
    50,516       51,777  
Accrued taxes
    9,302       15,111  
Accrued interest
    13,677       13,167  
Other
    23,330       25,311  
      491,403       403,618  
CAPITALIZATION:
               
Common stockholder's equity-
               
Common stock, $20 par value, authorized 5,400,000 shares-
               
4,427,577 shares outstanding
    88,552       88,552  
Other paid-in capital
    920,265       920,616  
Accumulated other comprehensive income
    3,006       4,946  
Retained earnings
    79,336       57,943  
Total common stockholder's equity
    1,091,159       1,072,057  
Long-term debt and other long-term obligations
    732,465       777,243  
      1,823,624       1,849,300  
NONCURRENT LIABILITIES:
               
Regulatory liabilities
    67,347       73,559  
Accumulated deferred income taxes
    220,500       210,776  
Retirement benefits
    41,644       41,298  
Asset retirement obligations
    83,129       81,849  
Other
    70,863       71,634  
      483,483       479,116  
COMMITMENTS AND CONTINGENCIES (Note 10)
               
    $ 2,798,510     $ 2,732,034  
                 
The accompanying Notes to Consolidated Financial Statements as they relate to Pennsylvania Electric Company are an
 
integral part of these balance sheets.
               

 
16

 
 
 
PENNSYLVANIA ELECTRIC COMPANY
 
CONSOLIDATED STATEMENTS OF CASH FLOWS
 
(Unaudited)
 
   
Three Months Ended
 
   
March 31,
 
   
Restated
       
   
 2008
   
 2007
 
   
(In thousands)
 
CASH FLOWS FROM OPERATING ACTIVITIES:
           
Net income
  $ 21,392     $ 31,744  
Adjustments to reconcile net income to net cash from operating activities-
               
Provision for depreciation
    12,516       11,777  
Amortization of regulatory assets
    16,346       15,394  
Deferral of new regulatory assets
    (3,526 )     (17,088 )
Deferred costs recoverable as regulatory assets
    (8,403 )     (18,433 )
Deferred income taxes and investment tax credits, net
    10,541       13,366  
Accrued compensation and retirement benefits
    (10,488 )     (8,786 )
Cash collateral
    301       1,450  
Pension trust contribution
    -       (13,436 )
Increase in operating assets-
               
Receivables
    (13,701 )     (30,050 )
Prepayments and other current assets
    (40,591 )     (36,225 )
Increase (Decrease) in operating liabilities-
               
Accounts payable
    (3,144 )     (46,168 )
Accrued taxes
    (5,809 )     (9,152 )
Accrued interest
    510       5,518  
Other
    4,991       3,920  
Net cash used for operating activities
    (19,065 )     (96,169 )
                 
CASH FLOWS FROM FINANCING ACTIVITIES:
               
New Financing-
               
Short-term borrowings, net
    118,209       119,361  
Redemptions and Repayments
               
Long-term debt
    (45,112 )     -  
Dividend Payments-
               
Common stock
    (20,000 )     -  
Net cash provided from financing activities
    53,097       119,361  
                 
CASH FLOWS FROM INVESTING ACTIVITIES:
               
Property additions
    (28,902 )     (20,404 )
Sales of investment securities held in trusts
    24,407       12,758  
Purchases of investment securities held in trusts
    (29,083 )     (15,509 )
Loan repayments from (loans to) associated companies, net
    (610 )     708  
Other
    153       (747 )
Net cash used for investing activities
    (34,035 )     (23,194 )
                 
Net decrease in cash and cash equivalents
    (3 )     (2 )
Cash and cash equivalents at beginning of period
    46       44  
Cash and cash equivalents at end of period
  $ 43     $ 42  
                 
The accompanying Notes to Consolidated Financial Statements as they relate to Pennsylvania Electric Company are
 
an integral part of these statements.
               
 
 
17

 
 
 
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)


1.     ORGANIZATION AND BASIS OF PRESENTATION

FirstEnergy is a diversified energy company that holds, directly or indirectly, all of the outstanding common stock of its principal subsidiaries: OE, CEI, TE, Penn (a wholly owned subsidiary of OE), ATSI, JCP&L, Met-Ed, Penelec, FENOC, FES and its subsidiaries FGCO and NGC, and FESC.

FirstEnergy and its subsidiaries follow GAAP and comply with the regulations, orders, policies and practices prescribed by the SEC, the FERC and, as applicable, the PUCO, the PPUC and the NJBPU. The preparation of financial statements in conformity with GAAP requires management to make periodic estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and disclosure of contingent assets and liabilities. Actual results could differ from these estimates. The reported results of operations are not indicative of results of operations for any future period.

These statements should be read in conjunction with the financial statements and notes included in the combined Annual Report on Form 10-K for the year ended December 31, 2007 for FirstEnergy, FES and the Companies. The consolidated unaudited financial statements of FirstEnergy, FES and each of the Companies reflect all normal recurring adjustments that, in the opinion of management, are necessary to fairly present results of operations for the interim periods. Certain prior year amounts have been reclassified to conform to the current year presentation. Unless otherwise indicated, defined terms used herein have the meanings set forth in the accompanying Glossary of Terms.

FirstEnergy and its subsidiaries consolidate all majority-owned subsidiaries over which they exercise control and, when applicable, entities for which they have a controlling financial interest. Intercompany transactions and balances are eliminated in consolidation. FirstEnergy consolidates a VIE (see Note 8) when it is determined to be the VIE's primary beneficiary. Investments in non-consolidated affiliates over which FirstEnergy and its subsidiaries have the ability to exercise significant influence, but not control (20-50% owned companies, joint ventures and partnerships) follow the equity method of accounting. Under the equity method, the interest in the entity is reported as an investment in the Consolidated Balance Sheets and the percentage share of the entity’s earnings is reported in the Consolidated Statements of Income.

The consolidated financial statements as of March 31, 2008 and for the three-month periods ended March 31, 2008 and 2007 have been reviewed by PricewaterhouseCoopers LLP, an independent registered public accounting firm. Their report (dated May 7, 2008, except as to the error correction described in Note 1, which is as of November 24, 2008) is included herein. The report of PricewaterhouseCoopers LLP states that they did not audit and they do not express an opinion on that unaudited financial information. Accordingly, the degree of reliance on their report on such information should be restricted in light of the limited nature of the review procedures applied. PricewaterhouseCoopers LLP is not subject to the liability provisions of Section 11 of the Securities Act of 1933 for their report on the unaudited financial information because that report is not a “report” or a “part” of a registration statement prepared or certified by PricewaterhouseCoopers LLP within the meaning of Sections 7 and 11 of the Securities Act of 1933.

Restatement of the Consolidated Statements of Cash Flows

OE, CEI, TE and Penelec are restating their respective Consolidated Statements of Cash Flows for the three months ended March 31, 2008, to correct common stock dividend payments reported in cash flows from financing activities. The consolidated statements of cash flows for those registrants, as originally filed, erroneously did not reflect the payment of common stock dividends in the first quarter of 2008, which were declared in the third quarter of 2007.  The corrections resulted in a corresponding change in operating liabilities - accounts payable, included in cash flows from operating activities.

This correction does not affect the respective registrants’ previously reported consolidated statements of income and comprehensive income for the three months ended March 31, 2008 and consolidated balance sheets as of March 31, 2008 contained in the combined Form 10-Q for the quarter ended March 31, 2008, as originally filed on May 8, 2008.
 
The effects of the corrections on OE’s, CEI’s, TE’s and Penelec’s Consolidated Statements of Cash Flows for the three months ended March 31, 2008 are as follows:

 
18

 

 
OE
           
             
   
Three Months
 
   
Ended March 31, 2008
 
   
As Previously
   
As
 
   
Reported
   
Restated
 
   
(In thousands)
 
CASH FLOWS FROM OPERATING ACTIVITIES:
           
Net income
  $ 43,909     $ 43,909  
Adjustments to reconcile net income to net cash from operating activities-
         
Provision for depreciation
    21,493       21,493  
Amortization of regulatory assets
    48,538       48,538  
Deferral of new regulatory assets
    (25,411 )     (25,411 )
Amortization of lease costs
    32,934       32,934  
Deferred income taxes and investment tax credits, net
    6,866       6,866  
Accrued compensation and retirement benefits
    (19,482 )     (19,482 )
Increase in operating assets-
               
Receivables
    (27,496 )     (27,496 )
Prepayments and other current assets
    (7,451 )     (7,451 )
Increase (decrease) in operating liabilities-
               
Accounts payable
    (18,939 )     (3,939 )
Accrued taxes
    2,991       2,991  
Accrued interest
    (5,919 )     (5,919 )
Electric service prepayment programs
    (10,028 )     (10,028 )
Other
    (2,066 )     (2,066 )
Net cash provided from operating activities
    39,939       54,939  
                 
CASH FLOWS FROM FINANCING ACTIVITIES:
               
Redemptions and Repayments-
               
Long-term debt
    (80 )     (80 )
Dividend Payments-
               
Common stock
    -       (15,000 )
Net cash used for financing activities
    (80 )     (15,080 )
                 
CASH FLOWS FROM INVESTING ACTIVITIES:
               
Property additions
    (49,011 )     (49,011 )
Sales of investment securities held in trusts
    62,344       62,344  
Purchases of investment securities held in trusts
    (63,797 )     (63,797 )
Loan repayments from associated companies, net
    6,534       6,534  
Cash investments
    147       147  
      3,924       3,924  
Net cash used for investing activities
    (39,859 )     (39,859 )
                 
Net change in cash and cash equivalents
  $ -     $ -  
 
 
19

 
CEI
           
             
   
Three Months
 
   
Ended March 31, 2008
 
   
As Previously
   
As
 
   
Reported
   
Restated
 
   
(In thousands)
 
CASH FLOWS FROM OPERATING ACTIVITIES:
           
Net income
  $ 57,851     $ 57,851  
Adjustments to reconcile net income to net cash from operating activities-
               
Provision for depreciation
    19,076       19,076  
Amortization of regulatory assets
    38,256       38,256  
Deferral of new regulatory assets
    (29,248 )     (29,248 )
Deferred rents and lease market valuation liability
    -       -  
Deferred income taxes and investment tax credits, net
    (4,965 )     (4,965 )
Accrued compensation and retirement benefits
    (3,507 )     (3,507 )
Decrease in operating assets-
               
Receivables
    90,280       90,280  
Prepayments and other current assets
    604       604  
Increase (decrease) in operating liabilities-
               
Accounts payable
    (28,889 )     1,111  
Accrued taxes
    23,196       23,196  
Accrued interest
    23,831       23,831  
Electric service prepayment programs
    (5,847 )     (5,847 )
Other
    (63 )     (63 )
Net cash provided from operating activities
    180,575       210,575  
                 
CASH FLOWS FROM FINANCING ACTIVITIES:
               
Redemptions and Repayments-
               
Long-term debt
    (165 )     (165 )
Short-term borrowings, net
    (177,960 )     (177,960 )
Dividend Payments-
               
Common stock
    -       (30,000 )
Net cash used for financing activities
    (178,125 )     (208,125 )
                 
CASH FLOWS FROM INVESTING ACTIVITIES:
               
Property additions
    (37,203 )     (37,203 )
Loans to associated companies, net
    (2,373 )     (2,373 )
Redemptions of lessor notes
    37,709       37,709  
Other
    (574 )     (574 )
Net cash used for investing activities
    (2,441 )     (2,441 )
                 
Net increase in cash and cash equivalents
  $ 9     $ 9  
 
 
20

 
TE
           
             
   
Three Months
 
   
Ended March 31, 2008
 
   
As Previously
   
As
 
   
Reported
   
Restated
 
   
(In thousands)
 
CASH FLOWS FROM OPERATING ACTIVITIES:
           
Net income
  $ 17,015     $ 17,015  
Adjustments to reconcile net income to net cash from operating activities-
               
Provision for depreciation
    9,025       9,025  
Amortization of regulatory assets
    25,025       25,025  
Deferral of new regulatory assets
    (9,494 )     (9,494 )
Deferred rents and lease market valuation liability
    6,099       6,099  
Deferred income taxes and investment tax credits, net
    (3,404 )     (3,404 )
Accrued compensation and retirement benefits
    (1,813 )     (1,813 )
Decrease in operating assets-
               
Receivables
    45,738       45,738  
Prepayments and other current assets
    181       181  
Increase (decrease) in operating liabilities-
               
Accounts payable
    (189,243 )     (174,243 )
Accrued taxes
    6,840       6,840  
Accrued interest
    4,663       4,663  
Electric service prepayment programs
    (2,670 )     (2,670 )
Other
    991       991  
Net cash used for operating activities
    (91,047 )     (76,047 )
                 
CASH FLOWS FROM FINANCING ACTIVITIES:
               
New Financing-
               
Short-term borrowings, net
    52,821       52,821  
Redemptions and Repayments-
               
Long-term debt
    (9 )     (9 )
Dividend Payments-
               
Common stock
    -       (15,000 )
Net cash provided from financing activities
    52,812       37,812  
                 
CASH FLOWS FROM INVESTING ACTIVITIES:
               
Property additions
    (19,435 )     (19,435 )
Loans repayments from (loans to) associated companies, net
    46,789       46,789  
Redemption of lessor notes
    11,989       11,989  
Sales of investment securities held in trusts
    3,908       3,908  
Purchases of investment securities held in trusts
    (4,715 )     (4,715 )
Other
    (110 )     (110 )
Net cash provided from investing activities
    38,426       38,426  
                 
Net increase in cash and cash equivalents
  $ 191     $ 191  
 
 
21

 
 
PENELEC
           
             
   
Three Months
 
   
Ended March 31, 2008
 
   
As Previously
   
As
 
   
Reported
   
Restated
 
   
(In thousands)
 
CASH FLOWS FROM OPERATING ACTIVITIES:
           
Net income
  $ 21,392     $ 21,392  
Adjustments to reconcile net income to net cash from operating activities-
         
Provision for depreciation
    12,516       12,516  
Amortization of regulatory assets
    16,346       16,346  
Deferral of new regulatory assets
    (3,526 )     (3,526 )
Deferred costs recoverable as regulatory assets
    (8,403 )     (8,403 )
Deferred income taxes and investment tax credits, net
    10,541       10,541  
Accrued compensation and retirement benefits
    (10,488 )     (10,488 )
Cash collateral
    301       301  
Increase in operating assets-
               
Receivables
    (13,701 )     (13,701 )
Prepayments and other current assets
    (40,591 )     (40,591 )
Increase (Decrease) in operating liabilities-
               
Accounts payable
    (23,144 )     (3,144 )
Accrued taxes
    (5,809 )     (5,809 )
Accrued interest
    510       510  
Other
    4,991       4,991  
Net cash used for operating activities
    (39,065 )     (19,065 )
                 
CASH FLOWS FROM FINANCING ACTIVITIES:
               
New Financing-
               
Short-term borrowings, net
    118,209       118,209  
Redemptions and Repayments
               
Long-term debt
    (45,112 )     (45,112 )
Dividend Payments-
               
Common stock
    -       (20,000 )
Net cash provided from financing activities
    73,097       53,097  
                 
CASH FLOWS FROM INVESTING ACTIVITIES:
               
Property additions
    (28,902 )     (28,902 )
Sales of investment securities held in trusts
    24,407       24,407  
Purchases of investment securities held in trusts
    (29,083 )     (29,083 )
Loans to associated companies, net
    (610 )     (610 )
Other
    153       153  
Net cash used for investing activities
    (34,035 )     (34,035 )
                 
Net decrease in cash and cash equivalents
  $ (3 )   $ (3 )
 
 
22

 

2.  EARNINGS PER SHARE

Basic earnings per share of common stock is computed using the weighted average of actual common shares outstanding during the respective period as the denominator. The denominator for diluted earnings per share of common stock reflects the weighted average of common shares outstanding plus the potential additional common shares that could result if dilutive securities and other agreements to issue common stock were exercised. The pool of stock-based compensation tax benefits is calculated in accordance with SFAS 123(R). On March 2, 2007, FirstEnergy repurchased approximately 14.4 million shares, or 4.5%, of its outstanding common stock through an accelerated share repurchase program at an initial price of approximately $900 million. A final purchase price adjustment of $51 million was settled in cash on December 13, 2007. The following table reconciles basic and diluted earnings per share of common stock:


Reconciliation of Basic and Diluted
 
Three Months Ended
March 31,
 
Earnings per Share of Common Stock
 
2008
 
2007
 
 
(In millions, except
 per share amounts)
Net income
 
$
276
 
$
290
 
               
Average shares of common stock outstanding – Basic
   
304
   
314
 
Assumed exercise of dilutive stock options and awards
   
3
   
2
 
Average shares of common stock outstanding – Dilutive
   
307
   
316
 
               
Basic earnings per share of common stock
 
$
0.91
 
$
0.92
 
Diluted earnings per share of common stock
 
$
0.90
 
$
0.92
 


3.  DIVESTITURES AND DISCONTINUED OPERATIONS

On March 7, 2008, FirstEnergy sold certain telecommunication assets, resulting in a net after-tax gain of $19.3 million. As a result of the sale, FirstEnergy adjusted goodwill by $1 million for the former GPU companies due to the realization of tax benefits that had been reserved in purchase accounting. The sale of assets did not meet the criteria for classification as discontinued operations as of March 31, 2008.

4.  FAIR VALUE MEASURES

Effective January 1, 2008, FirstEnergy adopted SFAS 157, which provides a framework for measuring fair value under GAAP and, among other things, requires enhanced disclosures about assets and liabilities recognized at fair value. FirstEnergy also adopted SFAS 159 on January 1, 2008, which provides the option to measure certain financial assets and financial liabilities at fair value. FirstEnergy has analyzed its financial assets and financial liabilities within the scope of SFAS 159 and, as of March 31, 2008, has elected not to record eligible assets and liabilities at fair value.

As defined in SFAS 157, fair value is the price that would be received for an asset or paid to transfer a liability (exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between willing market participants on the measurement date. SFAS 157 establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted market prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). The three levels of the fair value hierarchy defined by SFAS 157 are as follows:

Level 1 – Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those where transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. FirstEnergy’s Level 1 assets and liabilities primarily consist of exchange-traded derivatives and equity securities listed on active exchanges that are held in various trusts.

Level 2 – Pricing inputs are either directly or indirectly observable in the market as of the reporting date, other than quoted prices in active markets included in Level 1. FirstEnergy’s Level 2 consists primarily of investments in debt securities held in various trusts and commodity forwards. Additionally, Level 2 includes those financial instruments that are valued using models or other valuation methodologies based on assumptions that are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Instruments in this category include non-exchange-traded derivatives such as forwards and certain interest rate swaps.
 
 
23


 
Level 3 – Pricing inputs include inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value. FirstEnergy develops its view of the future market price of key commodities through a combination of market observation and assessment (generally for the short term) and fundamental modeling (generally for the longer term). Key fundamental electricity model inputs are generally directly observable in the market or derived from publicly available historic and forecast data. Some key inputs reflect forecasts published by industry leading consultants who generally employ similar fundamental modeling approaches. Fundamental model inputs and results, as well as the selection of consultants, reflect the consensus of appropriate FirstEnergy management. Level 3 instruments include those that may be more structured or otherwise tailored to customers’ needs. FirstEnergy’s Level 3 instruments consist of NUG contracts.

FirstEnergy utilizes market data and assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated, or generally unobservable. FirstEnergy primarily applies the market approach for recurring fair value measurements using the best information available. Accordingly, FirstEnergy maximizes the use of observable inputs and minimizes the use of unobservable inputs.

The following table sets forth FirstEnergy’s financial assets and financial liabilities that are accounted for at fair value by level within the fair value hierarchy as of March 31, 2008. As required by SFAS 157, assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. FirstEnergy’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.
 
   
March 31, 2008
 
Recurring Fair Value Measures
 
Level 1
 
Level 2
 
Level 3
 
Total
 
   
(In millions)
 
Assets:
                         
    Derivatives
 
$
4
 
$
98
 
$
-
 
$
102
 
    Nuclear decommissioning trusts(1)
   
1,070
   
953
   
-
   
2,023
 
    Other investments(2)
   
21
   
303
   
-
   
324
 
    Total
 
$
1,095
 
$
1,354
 
$
-
 
$
2,449
 
                           
Liabilities:
                         
    Derivatives
 
$
-
 
$
98
 
$
-
 
$
98
 
    NUG contracts(3)
   
-
   
-
   
682
   
682
 
    Total
 
$
-
 
$
98
 
$
682
 
$
780
 

(1)  
Balance excludes $2 million of receivables, payables and accrued income.
(2)  
Excludes $318 million of the cash surrender value of life insurance contracts.
(3)  
NUG contracts are completely offset by regulatory assets.

The determination of the above fair value measures takes into consideration various factors required under SFAS 157. These factors include the credit standing of the counterparties involved, the impact of credit enhancements (such as cash deposits, LOCs and priority interests) and the impact of nonperformance risk.

Exchange-traded derivative contracts, which include some futures and options, are generally based on unadjusted quoted market prices in active markets and are classified within Level 1. Forwards, options and swap contracts that are not exchange-traded are classified as Level 2 as the fair values of these items are based on ICE quotes or market transactions in the OTC markets. In addition, complex or longer term structured transactions can introduce the need for internally-developed model inputs that may not be observable in or corroborated by the market. When such inputs have a significant impact on the measurement of fair value, the instrument is classified as Level 3.

Nuclear decommissioning trusts consist of equity securities listed on active exchanges classified as Level 1 and various debt securities and collective trusts classified as Level 2. Other investments represent the NUG trusts, spent nuclear fuel trusts and rabbi trust investments, which primarily consist of various debt securities and collective trusts classified as Level 2.
 
 
24


 
The following table sets forth a reconciliation of changes in the fair value of NUG contracts classified as Level 3 in the fair value hierarchy for the three months ended March 31, 2008 (in millions):

Balance as of January 1, 2008
 
$
750
 
    Realized and unrealized gains (losses)(1)
   
(58
)
    Purchases, sales, issuances and settlements, net(1)
   
(10
)
    Net transfers to (from) Level 3
   
-
 
Balance as of March 31, 2008
 
$
682
 
         
Change in unrealized gains (losses) relating to
       
    instruments held as of March 31, 2008
 
$
(58
)
         
(1) Changes in the fair value of NUG contracts are completely offset by regulatory
     assets and do not impact earnings.
 
 

Under FSP FAS 157-2, FirstEnergy has elected to defer, for one year, the election of SFAS 157 for financial assets and financial liabilities measured at fair value on a non-recurring basis. FirstEnergy is currently evaluating the impact of FAS 157 on those financial assets and financial liabilities measured at fair value on a non-recurring basis.

5.  DERIVATIVE INSTRUMENTS

FirstEnergy is exposed to financial risks resulting from the fluctuation of interest rates and commodity prices, including prices for electricity, natural gas, coal and energy transmission. To manage the volatility relating to these exposures, FirstEnergy uses a variety of derivative instruments, including forward contracts, options, futures contracts and swaps. The derivatives are used principally for hedging purposes. FirstEnergy's Risk Policy Committee, comprised of members of senior management, provides general management oversight for risk management activities throughout FirstEnergy. They are responsible for promoting the effective design and implementation of sound risk management programs. They also oversee compliance with corporate risk management policies and established risk management practices.

FirstEnergy accounts for derivative instruments on its Consolidated Balance Sheet at their fair value unless they meet the normal purchases and normal sales criteria. Derivatives that meet those criteria are accounted for at cost. The changes in the fair value of derivative instruments that do not meet the normal purchases and normal sales criteria are recorded as other expense, as AOCL, or as part of the value of the hedged item, depending on whether or not it is designated as part of a hedge transaction, the nature of the hedge transaction and hedge effectiveness. FirstEnergy does not offset fair value for the right to reclaim collateral or the obligation to return collateral.

FirstEnergy hedges anticipated transactions using cash flow hedges. Such transactions include hedges of anticipated electricity and natural gas purchases and anticipated interest payments associated with future debt issues. The effective portion of such hedges are initially recorded in equity as other comprehensive income or loss and are subsequently included in net income as the underlying hedged commodities are delivered or interest payments are made. Gains and losses from any ineffective portion of cash flow hedges are included directly in earnings.

The net deferred losses of $84 million included in AOCL as of March 31, 2008, for derivative hedging activity, as compared to $75 million as of December 31, 2007, resulted from a net $21 million increase related to current hedging activity and a $12 million decrease due to net hedge losses reclassified to earnings during the three months ended March 31, 2008. Based on current estimates, approximately $19 million (after tax) of the net deferred losses on derivative instruments in AOCL as of March 31, 2008 are expected to be reclassified to earnings during the next twelve months as hedged transactions occur. The fair value of these derivative instruments fluctuate from period to period based on various market factors.

FirstEnergy has entered into swaps that have been designated as fair value hedges of fixed-rate, long-term debt issues to protect against the risk of changes in the fair value of fixed-rate debt instruments due to lower interest rates. Swap maturities, call options, fixed interest rates received, and interest payment dates match those of the underlying debt obligations. As of March 31, 2008, FirstEnergy had interest rate swaps with an aggregate notional value of $250 million and a fair value of $5 million.
 
 
25


 
During 2007 and the first three months of 2008, FirstEnergy entered into several forward starting swap agreements (forward swaps) in order to hedge a portion of the consolidated interest rate risk associated with the anticipated issuance of variable-rate, short-term debt and fixed-rate, long-term debt securities by one or more of its subsidiaries as outstanding debt matures during 2008 and 2009. These derivatives are treated as cash flow hedges, protecting against the risk of changes in future interest payments resulting from changes in benchmark U.S. Treasury and LIBOR rates between the date of hedge inception and the date of the debt issuance. During the first three months of 2008, FirstEnergy terminated swaps with a notional value of $300 million and entered into swaps with a notional value of $500 million. FirstEnergy paid $18 million related to the terminations, $1 million of which was deemed ineffective and recognized in current period earnings. FirstEnergy will recognize the remaining $17 million loss over the life of the associated future debt. As of March 31, 2008, FirstEnergy had forward swaps with an aggregate notional amount of $600 million and a fair value of $(8) million.

6.  ASSET RETIREMENT OBLIGATIONS

FirstEnergy has recognized applicable legal obligations under SFAS 143 for nuclear power plant decommissioning, reclamation of a sludge disposal pond and closure of two coal ash disposal sites. In addition, FirstEnergy has recognized conditional retirement obligations (primarily for asbestos remediation) in accordance with FIN 47.

The ARO liability of $1.3 billion as of March 31, 2008 is primarily related to the future nuclear decommissioning of the Beaver Valley, Davis-Besse, Perry and TMI-2 nuclear generating facilities. FirstEnergy utilized an expected cash flow approach to measure the fair value of the nuclear decommissioning ARO.

FirstEnergy maintains nuclear decommissioning trust funds that are legally restricted for purposes of settling the nuclear decommissioning ARO. As of March 31, 2008, the fair value of the decommissioning trust assets was approximately $2.0 billion.

The following tables analyze changes to the ARO balance during the first quarters of 2008 and 2007, respectively.

ARO Reconciliation
 
FirstEnergy
 
FES
 
OE
 
CEI
 
TE
 
JCP&L
 
Met-Ed
 
Penelec
 
   
(In millions)
 
Balance, January 1, 2008
 
$
1,267
 
$
810
 
$
94
 
$
2
 
$
28
 
$
90
 
$
161
 
$
82
 
Liabilities incurred
   
-
   
-
   
-
   
-
   
-
   
-
   
-
   
-
 
Liabilities settled
   
-
   
-
   
-
   
-
   
-
   
-
   
-
   
-
 
Accretion
   
20
   
14
   
1
   
-
   
1
   
1
   
2
   
1
 
Revisions in estimated cash flows
   
-
   
-
   
-
   
-
   
-
   
-
   
-
   
-
 
Balance, March 31, 2008
 
$
1,287
 
$
824
 
$
95
 
$
2
 
$
29
 
$
91
 
$
163
 
$
83
 
                                                   
Balance, January 1, 2007
 
$
1,190
 
$
760
 
$
88
 
$
2
 
$
27
 
$
84
 
$
151
 
$
77
 
Liabilities incurred
   
-
   
-
   
-
   
-
   
-
   
-
   
-
   
-
 
Liabilities settled
   
-
   
-
   
-
   
-
   
-
   
-
   
-
   
-
 
Accretion
   
18
   
12
   
1
   
-
   
-
   
2
   
2
   
1
 
Revisions in estimated cash flows
   
-
   
-
   
-
   
-
   
-
   
-
   
-
   
-
 
Balance, March 31, 2007
 
$
1,208
 
$
772
 
$
89
 
$
2
 
$
27
 
$
86
 
$
153
 
$
78
 


7.  PENSION AND OTHER POSTRETIREMENT BENEFITS

FirstEnergy provides noncontributory defined benefit pension plans that cover substantially all of its employees and those of its subsidiaries. The trusteed plans provide defined benefits based on years of service and compensation levels. FirstEnergy’s funding policy is based on actuarial computations using the projected unit credit method. FirstEnergy uses a December 31 measurement date for its pension and other postretirement benefit plans. The fair value of the plan assets represents the actual market value as of December 31, 2007. FirstEnergy also provides a minimum amount of noncontributory life insurance to retired employees in addition to optional contributory insurance. Health care benefits, which include certain employee contributions, deductibles and co-payments, are available upon retirement to employees hired prior to January 1, 2005, their dependents and, under certain circumstances, their survivors. FirstEnergy recognizes the expected cost of providing pension benefits and other postretirement benefits from the time employees are hired until they become eligible to receive those benefits. In addition, FirstEnergy has obligations to former or inactive employees after employment, but before retirement, for disability-related benefits.
 
 
26


 
The components of FirstEnergy's net periodic pension cost and other postretirement benefit cost (including amounts capitalized) for the three months ended March 31, 2008 and 2007, consisted of the following:

   
Pension Benefits
 
Other Postretirement Benefits
 
   
2008
 
2007
 
2008
 
2007
 
   
(In millions)
 
Service cost
 
$
21
 
$
21
 
$
5
 
$
5
 
Interest cost
   
72
   
71
   
18
   
17
 
Expected return on plan assets
   
(115
)
 
(112
)
 
(13
)
 
(13
)
Amortization of prior service cost
   
2
   
2
   
(37
)
 
(37
)
Recognized net actuarial loss
   
1
   
10
   
12
   
12
 
Net periodic cost (credit)
 
$
(19
)
$
(8)
 
$
(15
)
$
(16
)

Pension and postretirement benefit obligations are allocated to FirstEnergy’s subsidiaries employing the plan participants. The Companies capitalize employee benefits related to construction projects. The net periodic pension costs and net periodic postretirement benefit costs (including amounts capitalized) recognized by each of the Companies for the three months ended March 31, 2008 and 2007 were as follows:

   
Pension Benefit Cost (Credit)
 
Other Postretirement
Benefit Cost (Credit)
 
   
2008
 
2007
 
2008
 
2007
 
   
(In millions)
 
FES
 
$
4
 
$
-
 
$
(2
)
$
-
 
OE
   
(7
)
 
(4
)
 
(2
)
 
(3
)
CEI
   
(1
)
 
-
   
1
   
1
 
TE
   
(1
)
 
-
   
1
   
1
 
JCP&L
   
(4
)
 
(2
)
 
(4
)
 
(4
)
Met-Ed
   
(3
)
 
(2
)
 
(3
)
 
(2
)
Penelec
   
(3
)
 
(3
)
 
(3
)
 
(3
)
Other FirstEnergy
subsidiaries
   
(4
)
 
3
   
(3
)
 
(6
)
   
$
(19
)
$
(8
)
$
(15
)
$
(16
)

8.  VARIABLE INTEREST ENTITIES

FIN 46R addresses the consolidation of VIEs, including special-purpose entities, that are not controlled through voting interests or in which the equity investors do not bear the entity's residual economic risks and rewards. FirstEnergy and its subsidiaries consolidate VIEs when they are determined to be the VIE's primary beneficiary as defined by FIN 46R.

Trusts

FirstEnergy’s consolidated financial statements include PNBV and Shippingport, VIEs created in 1996 and 1997, respectively, to refinance debt originally issued in connection with sale and leaseback transactions. PNBV and Shippingport financial data are included in the consolidated financial statements of OE and CEI, respectively.

PNBV was established to purchase a portion of the lease obligation bonds issued in connection with OE’s 1987 sale and leaseback of its interests in the Perry Plant and Beaver Valley Unit 2. OE used debt and available funds to purchase the notes issued by PNBV. Ownership of PNBV includes a 3% equity interest by an unaffiliated third party and a 3% equity interest held by OES Ventures, a wholly owned subsidiary of OE. Shippingport was established to purchase all of the lease obligation bonds issued in connection with CEI’s and TE’s Bruce Mansfield Plant sale and leaseback transaction in 1987. CEI and TE used debt and available funds to purchase the notes issued by Shippingport.

Loss Contingencies

FES and the Ohio Companies are exposed to losses under their applicable sale-leaseback agreements upon the occurrence of certain contingent events that each company considers unlikely to occur. The maximum exposure under these provisions represents the net amount of casualty value payments due upon the occurrence of specified casualty events that render the applicable plant worthless. Net discounted lease payments would not be payable if the casualty loss payments are made. The following table shows each company’s net exposure to loss based upon the casualty value provisions mentioned above as of March 31, 2008:
 
 
27


 
   
Maximum Exposure
 
Discounted
Lease
Payments, net
 
Net
Exposure
   
(in millions)
FES
 
$
1,364
 
$
1,216
 
$
148
OE
 
819
 
628
 
191
CEI
 
782
 
77
 
705
TE
 
782
 
457
 
325

In October 2007, CEI and TE assigned their leasehold interests in the Bruce Mansfield Plant to FGCO. FGCO assumed all of CEI’s and TE’s obligations arising under those leases. FGCO subsequently transferred the Unit 1 portion of these leasehold interests, as well as FGCO’s leasehold interests under its July 2007 Bruce Mansfield Unit 1 sale and leaseback transaction to a newly formed wholly-owned subsidiary in December 2007. The subsidiary assumed all of the lessee obligations associated with the assigned interests. However, CEI and TE will remain primarily liable on the 1987 leases and related agreements as to the lessors and other parties to the agreements. FGCO remains primarily liable on the 2007 leases and related agreements, and FES remains primarily liable as a guarantor under the related 2007 guarantees, as to the lessors and other parties to the respective agreements. These assignments terminate automatically upon the termination of the underlying leases.

On March 3, 2008, notice was given to the nine owner trusts that are lessors under sale and leaseback transactions, originally entered into by TE in 1987, that NGC would acquire the related 18.26% undivided interest in Beaver Valley Unit 2 through the exercise of the periodic purchase option provided for in the applicable facility leases. The purchase price to be paid by NGC for the undivided interest will be equal to the higher of a specified casualty value under the applicable facility leases (approximately $239 million in the aggregate for the equity portion of all nine facility leases) and the fair market sales value of such undivided interests. Determination of the fair market sales value may become subject to an appraisal procedure provided for in the lease documentation. An additional payment of approximately $236 million would be required to prepay in full the outstanding principal of, and accrued but unpaid interest on, the lessor notes of the nine owner trusts. Alternatively, this amount would not be paid as part of the aggregate purchase price if the lessor notes are instead assumed at the time of the exercise of the option. If NGC determines to prepay the notes, it is possible that the proceeds from such prepayment may not be sufficient to pay the principal of, and interest on, the bonds as they become due. If that is the case, NGC would provide a mechanism to address any such potential shortfall in a timely manner.

Power Purchase Agreements

In accordance with FIN 46R, FirstEnergy evaluated its power purchase agreements and determined that certain NUG entities may be VIEs to the extent they own a plant that sells substantially all of its output to the Companies and the contract price for power is correlated with the plant’s variable costs of production. FirstEnergy, through its subsidiaries JCP&L, Met-Ed and Penelec, maintains approximately 30 long-term power purchase agreements with NUG entities. The agreements were entered into pursuant to the Public Utility Regulatory Policies Act of 1978. FirstEnergy was not involved in the creation of, and has no equity or debt invested in, these entities.

FirstEnergy has determined that for all but eight of these entities, neither JCP&L, Met-Ed nor Penelec have variable interests in the entities or the entities are governmental or not-for-profit organizations not within the scope of FIN 46R. JCP&L, Met-Ed or Penelec may hold variable interests in the remaining eight entities, which sell their output at variable prices that correlate to some extent with the operating costs of the plants. As required by FIN 46R, FirstEnergy periodically requests from these eight entities the information necessary to determine whether they are VIEs or whether JCP&L, Met-Ed or Penelec is the primary beneficiary. FirstEnergy has been unable to obtain the requested information, which in most cases was deemed by the requested entity to be proprietary. As such, FirstEnergy applied the scope exception that exempts enterprises unable to obtain the necessary information to evaluate entities under FIN 46R.

Since FirstEnergy has no equity or debt interests in the NUG entities, its maximum exposure to loss relates primarily to the above-market costs it may incur for power. FirstEnergy expects any above-market costs it incurs to be recovered from customers. Purchased power costs from these entities during the three months ended March 31, 2008 and 2007 are shown in the following table:

   
Three Months Ended
 
   
March 31,
 
   
2008
 
2007
 
   
(In millions)
 
JCP&L
 
$
19
 
$
20
 
Met-Ed
   
16
   
15
 
Penelec
   
8
   
8
 
   
$
43
 
$
43
 
 
 
28


 
Transition Bonds

The consolidated financial statements of FirstEnergy and JCP&L include the results of JCP&L Transition Funding and JCP&L Transition Funding II, wholly owned limited liability companies of JCP&L. In June 2002, JCP&L Transition Funding sold $320 million of transition bonds to securitize the recovery of JCP&L's bondable stranded costs associated with the previously divested Oyster Creek Nuclear Generating Station. In August 2006, JCP&L Transition Funding II sold $182 million of transition bonds to securitize the recovery of deferred costs associated with JCP&L’s supply of BGS.

JCP&L did not purchase and does not own any of the transition bonds, which are included as long-term debt on FirstEnergy's and JCP&L's Consolidated Balance Sheets. As of March 31, 2008, $391 million of the transition bonds were outstanding. The transition bonds are the sole obligations of JCP&L Transition Funding and JCP&L Transition Funding II and are collateralized by each company’s equity and assets, which consists primarily of bondable transition property.

Bondable transition property represents the irrevocable right under New Jersey law of a utility company to charge, collect and receive from its customers, through a non-bypassable TBC, the principal amount and interest on transition bonds and other fees and expenses associated with their issuance. JCP&L sold its bondable transition property to JCP&L Transition Funding and JCP&L Transition Funding II and, as servicer, manages and administers the bondable transition property, including the billing, collection and remittance of the TBC, pursuant to separate servicing agreements with JCP&L Transition Funding and JCP&L Transition Funding II. For the two series of transition bonds, JCP&L is entitled to aggregate quarterly servicing fees of $157,000 payable from TBC collections.

9.  INCOME TAXES

On January 1, 2007, FirstEnergy adopted FIN 48, which provides guidance for accounting for uncertainty in income taxes recognized in a company’s financial statements in accordance with SFAS 109. This interpretation prescribes a recognition threshold and measurement attribute for financial statement recognition and measurement of tax positions taken or expected to be taken on a company’s tax return. FIN 48 also provides guidance on derecognition, classification, interest, penalties, accounting in interim periods, disclosure and transition. The evaluation of a tax position in accordance with this interpretation is a two-step process. The first step is to determine if it is more likely than not that a tax position will be sustained upon examination, based on the merits of the position, and should therefore be recognized. The second step is to measure a tax position that meets the more likely than not recognition threshold to determine the amount of income tax benefit to recognize in the financial statements.

As of January 1, 2007, the total amount of FirstEnergy’s unrecognized tax benefits was $268 million. FirstEnergy recorded a $2.7 million cumulative effect adjustment to the January 1, 2007 balance of retained earnings to increase reserves for uncertain tax positions. Of the total amount of unrecognized income tax benefits, $92 million would favorably affect FirstEnergy’s effective tax rate upon recognition. The majority of items that would not have affected the effective tax rate would be purchase accounting adjustments to goodwill upon recognition. During the first three months of 2008 and 2007, there were no material changes to FirstEnergy’s unrecognized tax benefits. As of March 31, 2008, FirstEnergy expects that it is reasonably possible that $8 million of the unrecognized benefits will be resolved within the next twelve months and is included in the caption “accrued taxes,” with the remaining $263 million included in the caption “other non-current liabilities” on the Consolidated Balance Sheets.

FIN 48 also requires companies to recognize interest expense or income related to uncertain tax positions. That amount is computed by applying the applicable statutory interest rate to the difference between the tax position recognized in accordance with FIN 48 and the amount previously taken or expected to be taken on the tax return. FirstEnergy includes net interest and penalties in the provision for income taxes, consistent with its policy prior to implementing FIN 48. The net amount of interest accrued as of March 31, 2008 was $57 million, as compared to $53 million as of December 31, 2007. During the first three months of 2008 and 2007, there were no material changes to the amount of interest accrued.

FirstEnergy has tax returns that are under review at the audit or appeals level by the IRS and state tax authorities. All state jurisdictions are open from 2001-2007. The IRS began reviewing returns for the years 2001-2003 in July 2004 and several items are under appeal. The federal audits for the years 2004-2006 are expected to close before December 2008, but management anticipates certain items to be under appeal. The IRS began auditing the year 2007 in February 2007 and year 2008 in February 2008 under its Compliance Assurance Process experimental program. Neither audit is expected to close before December 2008. Management believes that adequate reserves have been recognized and final settlement of these audits is not expected to have a material adverse effect on FirstEnergy’s financial condition or results of operations.
 
 
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10.  COMMITMENTS, GUARANTEES AND CONTINGENCIES

(A)    GUARANTEES AND OTHER ASSURANCES

As part of normal business activities, FirstEnergy enters into various agreements on behalf of its subsidiaries to provide financial or performance assurances to third parties. These agreements include contract guarantees, surety bonds and LOCs. As of March 31, 2008, outstanding guarantees and other assurances aggregated approximately $4.4 billion, consisting of parental guarantees - $0.9 billion, subsidiaries’ guarantees - $2.7 billion, surety bonds - $0.1 billion and LOCs - $0.7 billion.

FirstEnergy guarantees energy and energy-related payments of its subsidiaries involved in energy commodity activities principally to facilitate normal physical transactions involving electricity, gas, emission allowances and coal. FirstEnergy also provides guarantees to various providers of credit support for the financing or refinancing by subsidiaries of costs related to the acquisition of property, plant and equipment. These agreements legally obligate FirstEnergy to fulfill the obligations of those subsidiaries directly involved in energy and energy-related transactions or financing where the law might otherwise limit the counterparties' claims. If demands of a counterparty were to exceed the ability of a subsidiary to satisfy existing obligations, FirstEnergy's guarantee enables the counterparty's legal claim to be satisfied by other FirstEnergy assets. The likelihood is remote that such parental guarantees of $0.4 billion (included in the $0.9 billion discussed above) as of March 31, 2008 would increase amounts otherwise payable by FirstEnergy to meet its obligations incurred in connection with financings and ongoing energy and energy-related activities.

While these types of guarantees are normally parental commitments for the future payment of subsidiary obligations, subsequent to the occurrence of a credit rating downgrade or “material adverse event,” the immediate posting of cash collateral or provision of an LOC may be required of the subsidiary. As of March 31, 2008, FirstEnergy's maximum exposure under these collateral provisions was $440 million.

Most of FirstEnergy's surety bonds are backed by various indemnities common within the insurance industry. Surety bonds and related guarantees of $66 million provide additional assurance to outside parties that contractual and statutory obligations will be met in a number of areas including construction contracts, environmental commitments and various retail transactions.

FirstEnergy has also guaranteed the obligations of the operators of the TEBSA project, up to a maximum of $2 million (subject to escalation) under the project's operations and maintenance agreement. In connection with the sale of TEBSA in January 2004, the purchaser indemnified FirstEnergy against any loss under this guarantee. FirstEnergy has also provided an LOC ($19 million as of March 31, 2008), which is renewable and declines yearly based upon the senior outstanding debt of TEBSA.

In July 2007, FGCO completed a sale and leaseback transaction for its 93.825% undivided interest in Bruce Mansfield Unit 1. FES has unconditionally and irrevocably guaranteed all of FGCO’s obligations under each of the leases. The related lessor notes and pass through certificates are not guaranteed by FES or FGCO, but the notes are secured by, among other things, each lessor trust’s undivided interest in Unit 1, rights and interests under the applicable lease and rights and interests under other related agreements, including FES’ lease guaranty.

(B)  
ENVIRONMENTAL MATTERS

Various federal, state and local authorities regulate FirstEnergy with regard to air and water quality and other environmental matters. The effects of compliance on FirstEnergy with regard to environmental matters could have a material adverse effect on FirstEnergy's earnings and competitive position to the extent that 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 estimates capital expenditures for environmental compliance of approximately $1.4 billion for the period 2008-2012.

FirstEnergy accrues environmental liabilities only when it concludes that it is probable that it has an obligation for such costs and can reasonably estimate the amount of such costs. Unasserted claims are reflected in FirstEnergy’s determination of environmental liabilities and are accrued in the period that they become both probable and reasonably estimable.
 
 
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Clean Air Act Compliance

FirstEnergy is required to meet federally-approved SO2 emissions regulations. Violations of such regulations can result in the shutdown of the generating unit involved and/or civil or criminal penalties of up to $32,500 for each day the unit is in violation. The EPA has an interim enforcement policy for SO2 regulations in Ohio that allows for compliance based on a 30-day averaging period. FirstEnergy believes it is currently in compliance with this policy, but cannot predict what action the EPA may take in the future with respect to the interim enforcement policy.

The EPA Region 5 issued a Finding of Violation and NOV to the Bay Shore Power Plant dated June 15, 2006, alleging violations to various sections of the CAA. FirstEnergy has disputed those alleged violations based on its CAA permit, the Ohio SIP and other information provided to the EPA at an August 2006 meeting with the EPA. The EPA has several enforcement options (administrative compliance order, administrative penalty order, and/or judicial, civil or criminal action) and has indicated that such option may depend on the time needed to achieve and demonstrate compliance with the rules alleged to have been violated. On June 5, 2007, the EPA requested another meeting to discuss “an appropriate compliance program” and a disagreement regarding the opacity limit applicable to the common stack for Bay Shore Units 2, 3 and 4.

FirstEnergy complies with SO2 reduction requirements under the Clean Air Act Amendments of 1990 by burning lower-sulfur fuel, generating more electricity from lower-emitting plants, and/or using emission allowances. NOX reductions required by the 1990 Amendments 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 NOX reductions at FirstEnergy's facilities. The EPA's NOX Transport Rule imposes uniform reductions of NOX emissions (an approximate 85% reduction in utility plant NOX emissions from projected 2007 emissions) across a region of nineteen states (including Michigan, New Jersey, Ohio and Pennsylvania) and the District of Columbia based on a conclusion that such NOX emissions are contributing significantly to ozone levels in the eastern United States. FirstEnergy believes its facilities are also complying with the NOX budgets established under SIPs through combustion controls and post-combustion controls, including Selective Catalytic Reduction and SNCR systems, and/or using emission allowances.

On May 22, 2007, FirstEnergy and FGCO received a notice letter, required 60 days prior to the filing of a citizen suit under the federal CAA, alleging violations of air pollution laws at the Bruce Mansfield Plant, including opacity limitations. Prior to the receipt of this notice, the Plant was subject to a Consent Order and Agreement with the Pennsylvania Department of Environmental Protection concerning opacity emissions under which efforts to achieve compliance with the applicable laws will continue. On October 18, 2007, PennFuture filed a complaint, joined by three of its members, in the United States District Court for the Western District of Pennsylvania. On January 11, 2008, FirstEnergy filed a motion to dismiss claims alleging a public nuisance. On April 24, 2008, the Court denied the motion to dismiss, but also ruled that monetary damages could not be recovered under the public nuisance claim.

On December 18, 2007, the state of New Jersey filed a CAA citizen suit alleging NSR violations at the Portland Generation Station against Reliant (the current owner and operator), Sithe Energy (the purchaser of the Portland Station from Met-Ed in 1999), GPU, Inc. and Met-Ed.  Specifically, New Jersey alleges that "modifications" at Portland Units 1 and 2 occurred between 1980 and 1995 without preconstruction NSR or permitting under the CAA's prevention of significant deterioration program, and seeks injunctive relief, penalties, attorney fees and mitigation of the harm caused by excess emissions. On March 14, 2008, Met-Ed filed a motion to dismiss the citizen suit claims against it and a stipulation in which the parties agreed that GPU, Inc. should be dismissed from this case. On March 26, 2008, GPU, Inc. was dismissed by the Court. Although it remains liable for civil or criminal penalties and fines that may be assessed relating to events prior to the sale of the Portland Station in 1999, Met-Ed is indemnified by Sithe Energy against any other liability arising under the CAA whether it arises out of pre-1999 or post-1999 events.

National Ambient Air Quality Standards

In March 2005, the EPA finalized the CAIR covering a total of 28 states (including Michigan, New Jersey, Ohio and Pennsylvania) and the District of Columbia based on proposed findings that air emissions from 28 eastern states and the District of Columbia significantly contribute to non-attainment of the NAAQS for fine particles and/or the "8-hour" ozone NAAQS in other states. CAIR requires reductions of NOX and SO2 emissions in two phases (Phase I in 2009 for NOX, 2010 for SO2 and Phase II in 2015 for both NOX and SO2). FirstEnergy's Michigan, Ohio and Pennsylvania fossil generation facilities will be subject to caps on SO2 and NOX emissions, whereas its New Jersey fossil generation facility will be subject to only a cap on NOX emissions. According to the EPA, SO2 emissions will be reduced by 45% (from 2003 levels) by 2010 across the states covered by the rule, with reductions reaching 73% (from 2003 levels) by 2015, capping SO2 emissions in affected states to just 2.5 million tons annually. NOX emissions will be reduced by 53% (from 2003 levels) by 2009 across the states covered by the rule, with reductions reaching 61% (from 2003 levels) by 2015, achieving a regional NOX cap of 1.3 million tons annually. CAIR has been challenged in the United States Court of Appeals for the District of Columbia. The future cost of compliance with these regulations may be substantial and may depend on the outcome of this litigation and how CAIR is ultimately implemented.
 
 
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Mercury Emissions

In December 2000, the EPA announced it would proceed with the development of regulations regarding hazardous air pollutants from electric power plants, identifying mercury as the hazardous air pollutant of greatest concern. In March 2005, the EPA finalized the CAMR, which provides a cap-and-trade program to reduce mercury emissions from coal-fired power plants in two phases; initially, capping national mercury emissions at 38 tons by 2010 (as a "co-benefit" from implementation of SO2 and NOX emission caps under the EPA's CAIR program) and 15 tons per year by 2018. Several states and environmental groups appealed the CAMR to the United States Court of Appeals for the District of Columbia. On February 8, 2008, the court vacated the CAMR ruling that the EPA failed to take the necessary steps to “de-list” coal-fired power plants from its hazardous air pollutant program and, therefore, could not promulgate a cap-and-trade program. The EPA must now seek further judicial review of that ruling or take regulatory action to promulgate new mercury emission standards for coal-fired power plants. FGCO’s future cost of compliance with mercury regulations may be substantial and will depend on the action taken by the EPA and on how they are ultimately implemented.

Pennsylvania has submitted a new mercury rule for EPA approval that does not provide a cap-and-trade approach as in the CAMR, but rather follows a command-and-control approach imposing emission limits on individual sources. It is anticipated that compliance with these regulations, if approved by the EPA and implemented, would not require the addition of mercury controls at the Bruce Mansfield Plant, FirstEnergy’s only Pennsylvania coal-fired power plant, until 2015, if at all.

W. H. Sammis Plant

In 1999 and 2000, the EPA issued an NOV and the DOJ filed a civil complaint against OE and Penn based on operation and maintenance of the W.H. Sammis Plant (Sammis NSR Litigation) and filed similar complaints involving 44 other U.S. power plants. This case, along with seven other similar cases, are referred to as the NSR cases.

On March 18, 2005, OE and Penn announced that they had reached a settlement with the EPA, the DOJ and three states (Connecticut, New Jersey and New York) that resolved all issues related to the Sammis NSR litigation. This settlement agreement, which is in the form of a consent decree, was approved by the court on July 11, 2005, and requires reductions of NOX and SO2 emissions at the Sammis, Burger, Eastlake and Mansfield coal-fired plants through the installation of pollution control devices and provides for stipulated penalties for failure to install and operate such pollution controls in accordance with that agreement. Consequently, if FirstEnergy fails to install such pollution control devices, for any reason, including, but not limited to, the failure of any third-party contractor to timely meet its delivery obligations for such devices, FirstEnergy could be exposed to penalties under the Sammis NSR Litigation consent decree. Capital expenditures necessary to complete requirements of the Sammis NSR Litigation consent decree are currently estimated to be $1.3 billion for 2008-2012 ($650 million of which is expected to be spent during 2008, with the largest portion of the remaining $650 million expected to be spent in 2009). This amount is included in the estimated capital expenditures for environmental compliance referenced above.

On April 2, 2007, the United States Supreme Court ruled that changes in annual emissions (in tons/year) rather than changes in hourly emissions rate (in kilograms/hour) must be used to determine whether an emissions increase triggers NSR. Subsequently, on May 8, 2007, the EPA proposed to revise the NSR regulations to utilize changes in the hourly emission rate (in kilograms/hour) to determine whether an emissions increase triggers NSR.   The EPA has not yet issued a final regulation. FGCO’s future cost of compliance with those regulations may be substantial and will depend on how they are ultimately implemented.

Climate Change

In December 1997, delegates to the United Nations' climate summit in Japan adopted an agreement, the Kyoto Protocol, to address global warming by reducing the amount of man-made GHG emitted by developed countries by 2012. The United States signed the Kyoto Protocol in 1998 but it failed to receive the two-thirds vote required for ratification by the United States Senate. However, the Bush administration has committed the United States to a voluntary climate change strategy to reduce domestic GHG intensity – the ratio of emissions to economic output – by 18% through 2012. Also, in an April 16, 2008 speech, President Bush set a policy goal of stopping the growth of GHG emissions by 2025, as the next step beyond the 2012 strategy. In addition, the EPACT established a Committee on Climate Change Technology to coordinate federal climate change activities and promote the development and deployment of GHG reducing technologies.

There are a number of initiatives to reduce GHG emissions under consideration at the federal, state and international level.  At the international level, efforts to reach a new global agreement to reduce GHG emissions post-2012 have begun with the Bali Roadmap, which outlines a two-year process designed to lead to an agreement in 2009. At the federal level, members of Congress have introduced several bills seeking to reduce emissions of GHG in the United States, and the Senate Environmental and Public Works Committees have passed one such bill. State activities, primarily the northeastern states participating in the Regional Greenhouse Gas Initiative and western states led by California, have coordinated efforts to develop regional strategies to control emissions of certain GHGs.
 
 
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On April 2, 2007, the United States Supreme Court found that the EPA has the authority to regulate CO2 emissions from automobiles as “air pollutants” under the CAA. Although this decision did not address CO2 emissions from electric generating plants, the EPA has similar authority under the CAA to regulate “air pollutants” from those and other facilities.

FirstEnergy cannot currently estimate the financial impact of climate change policies, although potential legislative or regulatory programs restricting CO2 emissions could require significant capital and other expenditures. The CO2 emissions per KWH of electricity generated by FirstEnergy is lower than many regional competitors due to its diversified generation sources, which include low or non-CO2 emitting gas-fired and nuclear generators.

Clean Water Act

Various water quality regulations, the majority of which are the result of the federal Clean Water Act and its amendments, apply to FirstEnergy's plants. In addition, Ohio, New Jersey and Pennsylvania have water quality standards applicable to FirstEnergy's 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.

On September 7, 2004, the EPA established new performance standards under Section 316(b) of the Clean Water Act for reducing impacts on fish and shellfish from cooling water intake structures at certain existing large electric generating plants. The regulations call for reductions in impingement mortality (when aquatic organisms are pinned against screens or other parts of a cooling water intake system) and entrainment (which occurs when aquatic life is drawn into a facility's cooling water system). On January 26, 2007, the United States Court of Appeals for the Second Circuit remanded portions of the rulemaking dealing with impingement mortality and entrainment back to the EPA for further rulemaking and eliminated the restoration option from the EPA’s regulations. On July 9, 2007, the EPA suspended this rule, noting that until further rulemaking occurs, permitting authorities should continue the existing practice of applying their best professional judgment (BPJ) to minimize impacts on fish and shellfish from cooling water intake structures. On April 14, 2008, the Supreme Court of the United States granted a petition for a writ of certiorari to review certain aspects of the Second Circuit’s decision. FirstEnergy is studying various control options and their costs and effectiveness. Depending on the results of such studies, the outcome of the Supreme Court’s review of the Second Circuit’s decision, the EPA’s further rulemaking and any action taken by the states exercising BPJ, the future costs of compliance with these standards may require material capital expenditures.

Regulation of Hazardous Waste

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 subsequently determined 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 non-hazardous waste.

Under NRC regulations, FirstEnergy must ensure that adequate funds will be available to decommission its nuclear facilities.  As of March 31, 2008, FirstEnergy had approximately $2.0 billion invested in external trusts to be used for the decommissioning and environmental remediation of Davis-Besse, Beaver Valley, Perry and TMI-2. As part of the application to the NRC to transfer the ownership of Davis-Besse, Beaver Valley and Perry to NGC in 2005, FirstEnergy agreed to contribute another $80 million to these trusts by 2010. Consistent with NRC guidance, utilizing a “real” rate of return on these funds of approximately 2% over inflation, these trusts are expected to exceed the minimum decommissioning funding requirements set by the NRC. Conservatively, these estimates do not include any rate of return that the trusts may earn over the 20-year plant useful life extensions that FirstEnergy (and Exelon for TMI-1 as it relates to the timing of the decommissioning of TMI-2) seeks for these facilities.

The Companies have been named as 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 may be liable on a joint and several basis. Therefore, environmental liabilities that are considered probable have been recognized on the Consolidated Balance Sheet as of March 31, 2008, based on estimates of the total costs of cleanup, the Companies' proportionate responsibility for such costs and the financial ability of other unaffiliated entities to pay. Total liabilities of approximately $92 million (JCP&L - $65 million, TE - $1 million, CEI - $1 million and FirstEnergy Corp. - $25 million) have been accrued through March 31, 2008. Included in the total for JCP&L are accrued liabilities of approximately $56 million for environmental remediation of former manufactured gas plants in New Jersey; which are being recovered by JCP&L through a non-bypassable SBC.
 
 
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(C)   OTHER LEGAL PROCEEDINGS

Power Outages and Related Litigation

In July 1999, the Mid-Atlantic States experienced a severe heat wave, which resulted in power outages throughout the service territories of many electric utilities, including JCP&L's territory. In an investigation into the causes of the outages and the reliability of the transmission and distribution systems of all four of New Jersey’s electric utilities, the NJBPU concluded that there was not a prima facie case demonstrating that, overall, JCP&L provided unsafe, inadequate or improper service to its customers. Two class action lawsuits (subsequently consolidated into a single proceeding) were filed in New Jersey Superior Court in July 1999 against JCP&L, GPU and other GPU companies, seeking compensatory and punitive damages arising from the July 1999 service interruptions in the JCP&L territory.

In August 2002, the trial court granted partial summary judgment to JCP&L and dismissed the plaintiffs' claims for consumer fraud, common law fraud, negligent misrepresentation, and strict product liability. In November 2003, the trial court granted JCP&L's motion to decertify the class and denied plaintiffs' motion to permit into evidence their class-wide damage model indicating damages in excess of $50 million. These class decertification and damage rulings were appealed to the Appellate Division. The Appellate Division issued a decision in July 2004, affirming the decertification of the originally certified class, but remanding for certification of a class limited to those customers directly impacted by the outages of JCP&L transformers in Red Bank, NJ, based on a common incident involving the failure of the bushings of two large transformers in the Red Bank substation resulting in planned and unplanned outages in the area during a 2-3 day period. In 2005, JCP&L renewed its motion to decertify the class based on a very limited number of class members who incurred damages and also filed a motion for summary judgment on the remaining plaintiffs’ claims for negligence, breach of contract and punitive damages. In July 2006, the New Jersey Superior Court dismissed the punitive damage claim and again decertified the class based on the fact that a vast majority of the class members did not suffer damages and those that did would be more appropriately addressed in individual actions. Plaintiffs appealed this ruling to the New Jersey Appellate Division which, in March 2007, reversed the decertification of the Red Bank class and remanded this matter back to the Trial Court to allow plaintiffs sufficient time to establish a damage model or individual proof of damages. JCP&L filed a petition for allowance of an appeal of the Appellate Division ruling to the New Jersey Supreme Court which was denied in May 2007.  Proceedings are continuing in the Superior Court and a case management conference with the presiding Judge is scheduled for June 13, 2008.  FirstEnergy is defending this class action but is unable to predict the outcome of this matter.  No liability has been accrued as of March 31, 2008.

Nuclear Plant Matters

On May 14, 2007, the Office of Enforcement of the NRC issued a DFI to FENOC, following FENOC’s reply to an April 2, 2007 NRC request for information, about two reports prepared by expert witnesses for an insurance arbitration (the insurance claim was subsequently withdrawn by FirstEnergy in December 2007) related to Davis-Besse. The NRC indicated that this information was needed for the NRC “to determine whether an Order or other action should be taken pursuant to 10 CFR 2.202, to provide reasonable assurance that FENOC will continue to operate its licensed facilities in accordance with the terms of its licenses and the Commission’s regulations.” FENOC was directed to submit the information to the NRC within 30 days. On June 13, 2007, FENOC filed a response to the NRC’s DFI reaffirming that it accepts full responsibility for the mistakes and omissions leading up to the damage to the reactor vessel head and that it remains committed to operating Davis-Besse and FirstEnergy’s other nuclear plants safely and responsibly. FENOC submitted a supplemental response clarifying certain aspects of the DFI response to the NRC on July 16, 2007. On August 15, 2007, the NRC issued a confirmatory order imposing these commitments. FENOC must inform the NRC’s Office of Enforcement after it completes the key commitments embodied in the NRC’s order. FENOC’s compliance with these commitments is subject to future NRC review.

Other Legal Matters

There are various lawsuits, claims (including claims for asbestos exposure) and proceedings related to FirstEnergy's normal business operations pending against FirstEnergy and its subsidiaries. The other potentially material items not otherwise discussed above are described below.
 
 
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On August 22, 2005, a class action complaint was filed against OE in Jefferson County, Ohio Common Pleas Court, seeking compensatory and punitive damages to be determined at trial based on claims of negligence and eight other tort counts alleging damages from W.H. Sammis Plant air emissions. The two named plaintiffs are also seeking injunctive relief to eliminate harmful emissions and repair property damage and the institution of a medical monitoring program for class members. On April 5, 2007, the Court rejected the plaintiffs’ request to certify this case as a class action and, accordingly, did not appoint the plaintiffs as class representatives or their counsel as class counsel. On July 30, 2007, plaintiffs’ counsel voluntarily withdrew their request for reconsideration of the April 5, 2007 Court order denying class certification and the Court heard oral argument on the plaintiffs’ motion to amend their complaint which OE opposed. On August 2, 2007, the Court denied the plaintiffs’ motion to amend their complaint. The plaintiffs have appealed the Court’s denial of the motion for certification as a class action and motion to amend their complaint.

JCP&L's bargaining unit employees filed a grievance challenging JCP&L's 2002 call-out procedure that required bargaining unit employees to respond to emergency power outages. On May 20, 2004, an arbitration panel concluded that the call-out procedure violated the parties' collective bargaining agreement. At the conclusion of the June 1, 2005 hearing, the arbitration panel decided not to hear testimony on damages and closed the proceedings. On September 9, 2005, the arbitration panel issued an opinion to award approximately $16 million to the bargaining unit employees. On February 6, 2006, a federal district court granted a union motion to dismiss, as premature, a JCP&L appeal of the award filed on October 18, 2005. A final order identifying the individual damage amounts was issued on October 31, 2007. The award appeal process was initiated. The union filed a motion with the federal court to confirm the award and JCP&L filed its answer and counterclaim to vacate the award on December 31, 2007. The court held a scheduling conference in April 2008 where it set a briefing schedule with all briefs to be concluded by July 2008. JCP&L recognized a liability for the potential $16 million award in 2005.

The union employees at the Bruce Mansfield Plant have been working without a labor contract since February 15, 2008. The parties are continuing to bargain with the assistance of a federal mediator. FirstEnergy has a strike mitigation plan ready in the event of a strike.

FirstEnergy accrues legal liabilities only when it concludes that it is probable that it has an obligation for such costs and can reasonably estimate the amount of such costs. If it were ultimately determined that FirstEnergy or its subsidiaries have legal liability or are otherwise made subject to liability based on the above matters, it could have a material adverse effect on FirstEnergy's or its subsidiaries' financial condition, results of operations and cash flows.

11.  REGULATORY MATTERS

(A) RELIABILITY INITIATIVES

In late 2003 and early 2004, a series of letters, reports and recommendations were issued from various entities, including governmental, industry and ad hoc reliability entities (PUCO, FERC, NERC and the U.S. – Canada Power System Outage Task Force) regarding enhancements to regional reliability. The proposed enhancements were divided into two groups:  enhancements that were to be completed in 2004; and enhancements that were to be completed after 2004.  In 2004, FirstEnergy completed all of the enhancements that were recommended for completion in 2004. FirstEnergy is also proceeding with the implementation of the recommendations that were to be completed subsequent to 2004 and will continue to periodically assess the FERC-ordered Reliability Study recommendations for forecasted 2009 system conditions, recognizing revised load forecasts and other changing system conditions which may impact the recommendations. Thus far, implementation of the recommendations has not required, nor is expected to require, substantial investment in new or material upgrades to existing equipment. The FERC or other applicable government agencies and reliability coordinators may, however, take a different view as to recommended enhancements or may recommend additional enhancements in the future that could require additional material expenditures.

As a result of outages experienced in JCP&L’s service area in 2002 and 2003, the NJBPU performed a review of JCP&L’s service reliability. On June 9, 2004, the NJBPU approved a stipulation that addresses a third-party consultant’s recommendations on appropriate courses of action necessary to ensure system-wide reliability. The stipulation incorporates the consultant’s focused audit of, and recommendations regarding, JCP&L’s Planning and Operations and Maintenance programs and practices. On June 1, 2005, the consultant completed his work and issued his final report to the NJBPU. On July 14, 2006, JCP&L filed a comprehensive response to the consultant’s report with the NJBPU. JCP&L will complete the remaining substantive work described in the stipulation in 2008.  JCP&L continues to file compliance reports with the NJBPU reflecting JCP&L’s activities associated with implementing the stipulation.
 
 
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In 2005, Congress amended the Federal Power Act to provide for federally-enforceable mandatory reliability standards. The mandatory reliability standards apply to the bulk power system and impose certain operating, record-keeping and reporting requirements on the Companies and ATSI. The NERC is charged with establishing and enforcing these reliability standards, although it has delegated day-to-day implementation and enforcement of its responsibilities to eight regional entities, including the ReliabilityFirst Corporation.  All of FirstEnergy’s facilities are located within the ReliabilityFirst region. FirstEnergy actively participates in the NERC and ReliabilityFirst stakeholder processes, and otherwise monitors and manages its companies in response to the ongoing development, implementation and enforcement of the reliability standards.

FirstEnergy believes that it is in compliance with all currently-effective and enforceable reliability standards.  Nevertheless, it is clear that NERC, ReliabilityFirst and the FERC will continue to refine existing reliability standards as well as to develop and adopt new reliability standards. The financial impact of complying with new or amended standards cannot be determined at this time. However, the 2005 amendments to the Federal Power Act provide that all prudent costs incurred to comply with the new reliability standards be recovered in rates. Still, any future inability on FirstEnergy’s part to comply with the reliability standards for its bulk power system could have a material adverse effect on its financial condition, results of operations and cash flows.

In April 2007, ReliabilityFirst performed a routine compliance audit of FirstEnergy’s bulk-power system within the Midwest ISO region and found it to be in full compliance with all audited reliability standards.  Similarly, ReliabilityFirst has scheduled a compliance audit of FirstEnergy’s bulk-power system within the PJM region in 2008. FirstEnergy currently does not expect any material adverse financial impact as a result of these audits.

(B) OHIO

On January 4, 2006, the PUCO issued an order authorizing the Ohio Companies to recover certain increased fuel costs through a fuel rider and to defer certain other increased fuel costs to be incurred from January 1, 2006 through December 31, 2008, including interest on the deferred balances. The order also provided for recovery of the deferred costs over a twenty-five-year period through distribution rates. On August 29, 2007, the Supreme Court of Ohio concluded that the PUCO violated a provision of the Ohio Revised Code by permitting the Ohio Companies “to collect deferred increased fuel costs through future distribution rate cases, or to alternatively use excess fuel-cost recovery to reduce deferred distribution-related expenses” and remanded the matter to the PUCO for further consideration. On September 10, 2007 the Ohio Companies filed an application with the PUCO that requested the implementation of two generation-related fuel cost riders to collect the increased fuel costs that were previously authorized to be deferred. On January 9, 2008 the PUCO approved the Ohio Companies’ proposed fuel cost rider to recover increased fuel costs to be incurred in 2008 commencing January 1, 2008 through December 31, 2008, which is expected to be approximately $189 million. In addition, the PUCO ordered the Ohio Companies to file a separate application for an alternate recovery mechanism to collect the 2006 and 2007 deferred fuel costs. On February 8, 2008, the Ohio Companies filed an application proposing to recover $226 million of deferred fuel costs and carrying charges for 2006 and 2007 pursuant to a separate fuel rider, with alternative options for the recovery period ranging from five to twenty-five years. This second application is currently pending before the PUCO and a hearing has been set for July 15, 2008.

The Ohio Companies filed an application and rate request for an increase in electric distribution rates with the PUCO on June 7, 2007. The requested increase is expected to be more than offset by the elimination or reduction of transition charges at the time the rates go into effect and would result in lowering the overall non-generation portion of the average electric bill for most Ohio customers.  The distribution rate increases reflect capital expenditures since the Ohio Companies’ last distribution rate proceedings, increases in operation and maintenance expenses and recovery of regulatory assets that were authorized in prior cases. On August 6, 2007, the Ohio Companies updated their filing supporting a distribution rate increase of $332 million. On December 4, 2007, the PUCO Staff issued its Staff Reports containing the results of their investigation into the distribution rate request. In its reports, the PUCO Staff recommended a distribution rate increase in the range of $161 million to $180 million, with $108 million to $127 million for distribution revenue increases and $53 million for recovery of costs deferred under prior cases. This amount excludes the recovery of deferred fuel costs, whose recovery is now being sought in a separate proceeding before the PUCO, discussed above. On January 3, 2008, the Ohio Companies and intervening parties filed objections to the Staff Reports and on January 10, 2008, the Ohio Companies filed supplemental testimony. Evidentiary hearings began on January 29, 2008 and continued through February 25, 2008. During the evidentiary hearings, the PUCO Staff submitted testimony decreasing their recommended revenue increase to a range of $114 million to $132 million. Additionally, in testimony submitted on February 11, 2008, the PUCO Staff adopted a position regarding interest deferred for RCP-related deferrals, line extension deferrals and transition tax deferrals that, if upheld by the PUCO, would result in the write-off of approximately $45 million of interest costs deferred through March 31, 2008 ($0.09 per share of common stock). The PUCO is expected to render its decision during the second or third quarter of 2008. The new rates would become effective January 1, 2009 for OE and TE, and approximately May 2009 for CEI.
 
 
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On July 10, 2007, the Ohio Companies filed an application with the PUCO requesting approval of a comprehensive supply plan for providing retail generation service to customers who do not purchase electricity from an alternative supplier, beginning January 1, 2009. The proposed competitive bidding process would average the results of multiple bidding sessions conducted at different times during the year. The final price per KWH would reflect an average of the prices resulting from all bids. In their filing, the Ohio Companies offered two alternatives for structuring the bids, either by customer class or a “slice-of-system” approach. A slice-of-system approach would require the successful bidder to be responsible for supplying a fixed percentage of the utility’s total load notwithstanding the customer’s classification. The proposal provides the PUCO with an option to phase in generation price increases for residential tariff groups who would experience a change in their average total price of 15 percent or more. The PUCO held a technical conference on August 16, 2007 regarding the filing. Initial and reply comments on the proposal were filed by various parties in September and October 2007, respectively. The proposal is currently pending before the PUCO.

On April 22, 2008, an amended version of Substitute SB221 was passed by the Ohio House of Representatives and sent back to the Ohio Senate for concurrence. On April 23, 2008, the Ohio Senate approved the House's amendments to Substitute SB221 and forwarded the bill to the Governor for signature, which he signed on May 1, 2008. Amended Substitute SB221 requires all electric distribution utilities to file an RSP, now called an ESP, with the PUCO. An ESP is required to contain a proposal for the supply and pricing of retail generation and may include proposals, without limitation, related to one or more of the following:

·  
automatic recovery of prudently incurred fuel, purchased power, emission allowance costs and federally mandated energy taxes;

·  
construction work in progress for costs of constructing an electric generating facility or environmental expenditure for any electric generating facility;

·  
costs of an electric generating facility;

·  
terms related to customer shopping, bypassability, standby, back-up and default service;

·  
accounting for deferrals related to stabilizing retail electric service;

·  
automatic increases or decreases in standard service offer price;

·  
phase-in and securitization;

·  
transmission service and related costs;

·  
distribution service and related costs; and

·  
economic development and energy efficiency.

A utility could also simultaneously file an MRO in which it would have to demonstrate the following objective market criteria: The utility or its transmission service affiliate belongs to a FERC-approved RTO having a market-monitor function and the ability to mitigate market power, and a published source exists that identifies information for traded electricity and energy products that are contracted for delivery two years into the future. The PUCO would test the ESP and its pricing and all other terms and conditions against the MRO and may only approve the ESP if it is found to be more favorable to customers. As part of an ESP with a plan period longer than three years, the PUCO shall prospectively determine every fourth year of the plan whether it is substantially likely the plan will provide the electric distribution utility a return on common equity significantly in excess of the return likely to be earned by publicly traded companies, including utilities, that face comparable business and financial risk (comparable companies). If so, the PUCO may terminate the ESP. Annually under an ESP, the PUCO shall determine whether an electric distribution utility's earned return on common equity is significantly in excess of returns earned on common equity during the same period by comparable companies, and if so, shall require the utility to return such excess to customers by prospective adjustments. Amended Substitute SB221 also includes provisions dealing with advanced and renewable energy standards that contemplate 25% of electrical usage from these sources by 2025. Energy efficiency measures in the bill require energy savings in excess of 22% by 2025. Requirements are in place to meet annual benchmarks for renewable energy resources and energy efficiency, subject to review by the PUCO. FirstEnergy is currently evaluating this legislation and expects to file an ESP in the second or third quarter of 2008.
 
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(C) PENNSYLVANIA

Met-Ed and Penelec purchase a portion of their PLR and default service requirements from FES through a fixed-price partial requirements wholesale power sales agreement. The agreement allows Met-Ed and Penelec to sell the output of NUG energy to the market and requires FES to provide energy at fixed prices to replace any NUG energy sold to the extent needed for Met-Ed and Penelec to satisfy their PLR and default service obligations. The fixed price under the agreement is expected to remain below wholesale market prices during the term of the agreement. If Met-Ed and Penelec were to replace the entire FES supply at current market power prices without corresponding regulatory authorization to increase their generation prices to customers, each company would likely incur a significant increase in operating expenses and experience a material deterioration in credit quality metrics. Under such a scenario, each company's credit profile would no longer be expected to support an investment grade rating for their fixed income securities. Based on the PPUC’s January 11, 2007 order described below, if FES ultimately determines to terminate, reduce, or significantly modify the agreement prior to the expiration of Met-Ed’s and Penelec’s generation rate caps in 2010, timely regulatory relief is not likely to be granted by the PPUC.

Met-Ed and Penelec made a comprehensive transition rate filing with the PPUC on April 10, 2006 to address a number of transmission, distribution and supply issues. If Met-Ed's and Penelec's preferred approach involving accounting deferrals had been approved, annual revenues would have increased by $216 million and $157 million, respectively. That filing included, among other things, a request to charge customers for an increasing amount of market-priced power procured through a CBP as the amount of supply provided under the then existing FES agreement was to be phased out. Met-Ed and Penelec also requested approval of a January 12, 2005 petition for the deferral of transmission-related costs incurred during 2006. In this rate filing, Met-Ed and Penelec requested recovery of annual transmission and related costs incurred on or after January 1, 2007, plus the amortized portion of 2006 costs over a ten-year period, along with applicable carrying charges, through an adjustable rider. Changes in the recovery of NUG expenses and the recovery of Met-Ed's non-NUG stranded costs were also included in the filing. On May 4, 2006, the PPUC consolidated the remand of the FirstEnergy and GPU merger proceeding, related to the quantification and allocation of merger savings, with the comprehensive transition rate filing case.

The PPUC entered its opinion and order in the comprehensive rate filing proceeding on January 11, 2007. The order approved the recovery of transmission costs, including the transmission-related deferral for January 1, 2006 through January 10, 2007, and determined that no merger savings from prior years should be considered in determining customers’ rates. The request for increases in generation supply rates was denied as were the requested changes to NUG expense recovery and Met-Ed’s non-NUG stranded costs. The order decreased Met-Ed’s and Penelec’s distribution rates by $80 million and $19 million, respectively. These decreases were offset by the increases allowed for the recovery of transmission costs. Met-Ed’s and Penelec’s request for recovery of Saxton decommissioning costs was granted and, in January 2007, Met-Ed and Penelec recognized income of $15 million and $12 million, respectively, to establish regulatory assets for those previously expensed decommissioning costs. Overall rates increased by 5.0% for Met-Ed ($59 million) and 4.5% for Penelec ($50 million).

On March 30, 2007, MEIUG and PICA filed a Petition for Review with the Commonwealth Court of Pennsylvania asking the court to review the PPUC’s determination on transmission (including congestion) and the transmission deferral. Met-Ed and Penelec filed a Petition for Review on April 13, 2007 on the issues of consolidated tax savings and the requested generation rate increase. The OCA filed its Petition for Review on April 13, 2007, on the issues of transmission (including congestion) and recovery of universal service costs from only the residential rate class. From June through October 2007, initial responsive and reply briefs were filed by various parties. Oral arguments are scheduled to take place in September 2008. If Met-Ed and Penelec do not prevail on the issue of congestion, it could have a material adverse effect on the results of operations of Met-Ed, Penelec and FirstEnergy.

On April 14, 2008, Met-Ed and Penelec filed annual updates to the TSC rider for the period June 1, 2008, through May 31, 2009. The proposed TSCs include a component for under-recovery of actual transmission costs incurred during the prior period (Met-Ed - $144 million and Penelec - $4 million) and future transmission cost projections for June 2008 through May 2009 (Met-Ed - $258 million and Penelec - $92 million). Met-Ed has proposed a transition approach that would recover past under-recovered costs plus carrying charges through the new TSC over thirty-one months and defer a portion of the projected costs ($92 million) plus carrying charges for recovery through future TSCs by December 31, 2010.

On March 13, 2008, the PPUC approved the residential procurement process in Penn’s Joint Petition for Settlement. This RFP process calls for load-following, full-requirements contracts for default service procurement for residential customers for the period covering June 1, 2008 through May 31, 2011. The PPUC had previously approved the default service procurement processes for commercial and industrial customers. The default service procurement for small commercial customers was conducted through multiple RFPs, while the default service procurement for large commercial and industrial customers will utilize hourly pricing. Bids in the two RFPs for small commercial load were approved by the PPUC on February 22, 2008, and March 20, 2008. On March 28, 2008, Penn filed compliance tariffs with the new default service generation rates based on the approved RFP bids for small commercial customers which the PPUC then certified on April 4, 2008. On April 14, 2008, the first RFP for residential customers’ load was held consisting of tranches for both 12 and 24-month supply. The PPUC approved the bids on April 16, 2008. The second RFP is scheduled to be held on May 14, 2008, after which time the PPUC is expected to approve the new rates to go into effect June 1, 2008.

 
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On February 1, 2007, the Governor of Pennsylvania proposed an EIS. The EIS includes four pieces of proposed legislation that, according to the Governor, is designed to reduce energy costs, promote energy independence and stimulate the economy. Elements of the EIS include the installation of smart meters, funding for solar panels on residences and small businesses, conservation and demand reduction programs to meet energy growth, a requirement that electric distribution companies acquire power that results in the “lowest reasonable rate on a long-term basis,” the utilization of micro-grids and a three year phase-in of rate increases. On July 17, 2007 the Governor signed into law two pieces of energy legislation. The first amended the Alternative Energy Portfolio Standards Act of 2004 to, among other things, increase the percentage of solar energy that must be supplied at the conclusion of an electric distribution company’s transition period. The second law allows electric distribution companies, at their sole discretion, to enter into long term contracts with large customers and to build or acquire interests in electric generation facilities specifically to supply long-term contracts with such customers. A special legislative session on energy was convened in mid-September 2007 to consider other aspects of the EIS. The Pennsylvania House and Senate on March 11, 2008 and December 12, 2007, respectively, passed different versions of bills to fund the Governor’s EIS proposal. Neither chamber has formally considered the other’s bill. On February 12, 2008, the Pennsylvania House passed House Bill 2200 which provides for energy efficiency and demand management programs and targets as well as the installation of smart meters within ten years. Other legislation has been introduced to address generation procurement, expiration of rate caps, conservation and renewable energy. The final form of this pending legislation is uncertain. Consequently, FirstEnergy is unable to predict what impact, if any, such legislation may have on its operations.

(D) NEW JERSEY

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 NUG agreements exceed amounts collected through BGS and NUGC rates and market sales of NUG energy and capacity. As of March 31, 2008, the accumulated deferred cost balance totaled approximately $264 million.

In accordance with an April 28, 2004 NJBPU order, JCP&L filed testimony on June 7, 2004 supporting continuation of the current level and duration of the funding of TMI-2 decommissioning costs by New Jersey customers without a reduction, termination or capping of the funding. On September 30, 2004, JCP&L filed an updated TMI-2 decommissioning study. This study resulted in an updated total decommissioning cost estimate of $729 million (in 2003 dollars) compared to the estimated $528 million (in 2003 dollars) from the prior 1995 decommissioning study. The DRA filed comments on February 28, 2005 requesting that decommissioning funding be suspended. On March 18, 2005, JCP&L filed a response to those comments. JCP&L responded to additional NJBPU staff discovery requests in May and November 2007 and also submitted comments in the proceeding in November 2007. A schedule for further NJBPU proceedings has not yet been set.

On August 1, 2005, the NJBPU established a proceeding to determine whether additional ratepayer protections are required at the state level in light of the repeal of the PUHCA pursuant to the EPACT. The NJBPU approved regulations effective October 2, 2006 that prevent a holding company that owns a gas or electric public utility from investing more than 25% of the combined assets of its utility and utility-related subsidiaries into businesses unrelated to the utility industry. These regulations are not expected to materially impact FirstEnergy or JCP&L. Also, in the same proceeding, the NJBPU Staff issued an additional draft proposal on March 31, 2006 addressing various issues including access to books and records, ring-fencing, cross subsidization, corporate governance and related matters. With the approval of the NJBPU Staff, the affected utilities jointly submitted an alternative proposal on June 1, 2006. The NJBPU Staff circulated revised drafts of the proposal to interested stakeholders in November 2006 and again in February 2007. On February 1, 2008, the NJBPU accepted proposed rules for publication in the New Jersey Register on March 17, 2008. A public hearing on these proposed rules was held on April 23, 2008 with comments from interested parties due on May 16, 2008.

New Jersey statutes require that the state periodically undertake a planning process, known as the EMP, to address energy related issues including energy security, economic growth, and environmental impact. The EMP is to be developed with involvement of the Governor’s Office and the Governor’s Office of Economic Growth, and is to be prepared by a Master Plan Committee, which is chaired by the NJBPU President and includes representatives of several State departments. In October 2006, the current EMP process was initiated through the creation of a number of working groups to obtain input from a broad range of interested stakeholders including utilities, environmental groups, customer groups, and major customers. In addition, public stakeholder meetings were held in the fall of 2006 and in early 2007.

On April 17, 2008, a draft EMP was released for public comment. The draft EMP establishes four major goals:

·  
maximize energy efficiency to achieve a 20% reduction in energy consumption by 2020;

·  
reduce peak demand for electricity by 5,700 MW by 2020 (amounting to about a 22% reduction in projected demand);

 
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·  
meet 22.5% of the state’s electricity needs with renewable energy by 2020; and

·  
develop low carbon emitting, efficient power plants and close the gap between the supply and demand for electricity.

Following the public comment period which is expected to extend into July 2008, a final EMP will be issued to be followed by appropriate legislation and regulation as necessary. At this time, FirstEnergy cannot predict the outcome of this process nor determine the impact, if any, such legislation or regulation may have on its operations or those of JCP&L.

On February 13, 2007, the NJBPU Staff informally issued a draft proposal relating to changes to the regulations addressing electric distribution service reliability and quality standards. Meetings between the NJBPU Staff and interested stakeholders to discuss the proposal were held and additional, revised informal proposals were subsequently circulated by the Staff. On September 4, 2007, proposed regulations were published in the New Jersey Register, which proposal will be subsequently considered by the NJBPU following comments that were submitted in September and October 2007. Final regulations (effective upon publication) were published in the New Jersey Register March 17, 2008. Upon preliminary review of the new regulations, FirstEnergy does not expect a material impact on its operations or those of JCP&L.

(E) FERC MATTERS

Transmission Service between MISO and PJM

On November 18, 2004, the FERC issued an order eliminating the through and out rate for transmission service between the MISO and PJM regions. The FERC’s intent was to eliminate so-called “pancaking” of transmission charges between the MISO and PJM regions. The FERC also ordered the MISO, PJM and the transmission owners within MISO and PJM to submit compliance filings containing a rate mechanism to recover lost transmission revenues created by elimination of this charge (referred to as the Seams Elimination Cost Adjustment or “SECA”) during a 16-month transition period. The FERC issued orders in 2005 setting the SECA for hearing. The presiding judge issued an initial decision on August 10, 2006, rejecting the compliance filings made by MISO, PJM, and the transmission owners, and directing new compliance filings. This decision is subject to review and approval by the FERC. Briefs addressing the initial decision were filed on September 11, 2006 and October 20, 2006. A final order could be issued by the FERC in the second quarter of 2008.
 
PJM Transmission Rate Design

On January 31, 2005, certain PJM transmission owners made filings with the FERC pursuant to a settlement agreement previously approved by the FERC. JCP&L, Met-Ed and Penelec were parties to that proceeding and joined in two of the filings. In the first filing, the settling transmission owners submitted a filing justifying continuation of their existing rate design within the PJM RTO. Hearings were held and numerous parties appeared and litigated various issues concerning PJM rate design; notably AEP, which proposed to create a "postage stamp", or average rate for all high voltage transmission facilities across PJM and a zonal transmission rate for facilities below 345 kV. This proposal would have the effect of shifting recovery of the costs of high voltage transmission lines to other transmission zones, including those where JCP&L, Met-Ed, and Penelec serve load. On April 19, 2007, the FERC issued an order finding that the PJM transmission owners’ existing “license plate” or zonal rate design was just and reasonable and ordered that the current license plate rates for existing transmission facilities be retained. On the issue of rates for new transmission facilities, the FERC directed that costs for new transmission facilities that are rated at 500 kV or higher are to be collected from all transmission zones throughout the PJM footprint by means of a postage-stamp rate. Costs for new transmission facilities that are rated at less than 500 kV, however, are to be allocated on a “beneficiary pays” basis. The FERC found that PJM’s current beneficiary-pays cost allocation methodology is not sufficiently detailed and, in a related order that also was issued on April 19, 2007, directed that hearings be held for the purpose of establishing a just and reasonable cost allocation methodology for inclusion in PJM’s tariff.

On May 18, 2007, certain parties filed for rehearing of the FERC’s April 19, 2007 order. On January 31, 2008, the requests for rehearing were denied. The FERC’s orders on PJM rate design will prevent the allocation of a portion of the revenue requirement of existing transmission facilities of other utilities to JCP&L, Met-Ed and Penelec. In addition, the FERC’s decision to allocate the cost of new 500 kV and above transmission facilities on a PJM-wide basis will reduce future transmission revenue recovery from the JCP&L, Met-Ed and Penelec zones. A partial settlement agreement addressing the “beneficiary pays” methodology for below 500 kV facilities, but excluding the issue of allocating new facilities costs to merchant transmission entities, was filed on September 14, 2007. The agreement was supported by the FERC’s Trial Staff, and was certified by the Presiding Judge. The FERC’s action on the settlement agreement is pending. The remaining merchant transmission cost allocation issues will proceed to hearing in May 2008. On February 13, 2008, AEP appealed the FERC’s orders to the federal Court of Appeals for the D.C. Circuit. The Illinois Commerce Commission, the PUCO and Dayton Power & Light have also appealed these orders to the Seventh Circuit Court of Appeals. The appeals of these parties and others have been consolidated for argument in the Seventh Circuit.

 
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Post Transition Period Rate Design

The FERC had directed MISO, PJM, and the respective transmission owners to make filings on or before August 1, 2007 to reevaluate transmission rate design within MISO, and between MISO and PJM. On August 1, 2007, filings were made by MISO, PJM, and the vast majority of transmission owners, including FirstEnergy affiliates, which proposed to retain the existing transmission rate design. These filings were approved by the FERC on January 31, 2008. As a result of the FERC’s approval, the rates charged to FirstEnergy’s load-serving affiliates for transmission service over existing transmission facilities in MISO and PJM are unchanged. In a related filing, MISO and MISO transmission owners requested that the current MISO pricing for new transmission facilities that spreads 20% of the cost of new 345 kV and higher transmission facilities across the entire MISO footprint (known as the RECB methodology) be retained.

On September 17, 2007, AEP filed a complaint under Sections 206 and 306 of the Federal Power Act seeking to have the entire transmission rate design and cost allocation methods used by MISO and PJM declared unjust, unreasonable, and unduly discriminatory, and to have the FERC fix a uniform regional transmission rate design and cost allocation method for the entire MISO and PJM “Super Region” that recovers the average cost of new and existing transmission facilities operated at voltages of 345 kV and above from all transmission customers. Lower voltage facilities would continue to be recovered in the local utility transmission rate zone through a license plate rate. AEP requested a refund effective October 1, 2007, or alternatively, February 1, 2008. On January 31, 2008, the FERC issued an order denying the complaint. A rehearing request by AEP is pending before the FERC.

Distribution of MISO Network Service Revenues

Effective February 1, 2008, the MISO Transmission Owners Agreement provides for a change in the method of distributing transmission revenues among the transmission owners. MISO and a majority of the MISO transmission owners filed on December 3, 2007 to change the MISO tariff to clarify, for purposes of distributing network transmission revenue to the transmission owners, that all network transmission service revenues, whether collected by MISO or directly by the transmission owner, are included in the revenue distribution calculation.  This clarification was necessary because some network transmission service revenues are collected and retained by transmission owners in states where retail choice does not exist, and their “unbundled” retail load is currently exempt from MISO network service charges. The tariff changes filed with the FERC ensure that revenues collected by transmission owners from bundled load are taken into account in the revenue distribution calculation, and that transmission owners with bundled load do not collect more than their revenue requirements. Absent the changes, transmission owners, and ultimately their customers, with unbundled load or in retail choice states, such as ATSI, would subsidize transmission owners with bundled load, who would collect their revenue requirement from bundled load, plus share in revenues collected by MISO from unbundled customers. This would result in a large revenue shortfall for ATSI, which would eventually be passed on to customers in the form of higher transmission rates as calculated pursuant to ATSI’s Attachment O formula under the MISO tariff.

Numerous parties filed in support of the tariff changes, including the public service commissions of Michigan, Ohio and Wisconsin. Ameren filed a protest on December 26, 2007, arguing that the December 3, 2007 filing violates the MISO Transmission Owners’ Agreement as well as an agreement among Ameren (Union Electric), MISO, and the Missouri Public Service Commission, which provides that Union Electric’s bundled load cannot be charged by MISO for network service. On February 2, 2008, the FERC issued an order conditionally accepting the tariff amendment subject to a minor compliance filing, which was made on March 3, 2008. This order ensures that ATSI will continue to receive transmission revenues from MISO equivalent to its transmission revenue requirement. A rehearing request by Ameren is pending before the FERC.

On February 1, 2008, MISO filed a request to continue using the existing revenue distribution methodology on an interim basis pending amendment of the MISO Transmission Owners’ Agreement. This request was accepted by the FERC on March 13, 2008. On that same day, MISO and the MISO transmission owners made a filing to amend the Transmission Owners’ Agreement to effectively continue the distribution of transmission revenues that was in effect prior to February 1, 2008. This matter is currently pending before the FERC.

MISO Ancillary Services Market and Balancing Area Consolidation

MISO made a filing on September 14, 2007 to establish an ASM for regulation, spinning and supplemental reserves, to consolidate the existing 24 balancing areas within the MISO footprint, and to establish MISO as the NERC registered balancing authority for the region. This filing would permit load serving entities to purchase their operating reserve requirements in a competitive market. FirstEnergy supports the proposal to establish markets for Ancillary Services and consolidate existing balancing areas. On February 25, 2008, the FERC issued an order approving the ASM subject to certain compliance filings. MISO has since notified the FERC that the start of its ASM is delayed until September of 2008.

 
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Duquesne’s Request to Withdraw from PJM

On November 8, 2007, Duquesne Light Company (Duquesne) filed a request with the FERC to exit PJM and to join the MISO. In its filing, Duquesne asked the FERC to be relieved of certain capacity payment obligations to PJM for capacity auctions conducted prior to its departure from PJM, but covering service for planning periods through May 31, 2011. Duquesne asserted that its primary reason for exiting PJM is to avoid paying future obligations created by PJM’s forward capacity market. FirstEnergy believes that Duquesne’s filing did not identify or address numerous legal, financial or operational issues that are implicated or affected directly by Duquesne’s proposal. Consequently, FirstEnergy submitted responsive filings that, while conceding Duquesne’s rights to exit PJM, contested various aspects of Duquesne’s proposal. FirstEnergy particularly focused on Duquesne’s proposal that it be allowed to exit PJM without payment of its share of existing capacity market commitments. FirstEnergy also objected to Duquesne’s failure to address the firm transmission service requirements that would be necessary for FirstEnergy to continue to use the Beaver Valley Plant to meet existing commitments in the PJM capacity markets and to serve native load. Other market participants also submitted filings contesting Duquesne’s plans.

On January 17, 2008, the FERC conditionally approved Duquesne’s request to exit PJM. Among other conditions, the FERC obligated Duquesne to pay the PJM capacity obligations through May 31, 2011. The FERC’s order took notice of the numerous transmission and other issues raised by FirstEnergy and other parties to the proceeding, but did not provide any responsive rulings or other guidance. Rather, the FERC ordered Duquesne to make a compliance filing in forty-five days detailing how Duquesne will satisfy its obligations under the PJM Transmission Owners’ Agreement. The FERC likewise directed the MISO to submit detailed plans to integrate Duquesne into the MISO. Finally, the FERC directed MISO and PJM to work together to resolve the substantive and procedural issues implicated by Duquesne’s transition into the MISO. These issues remain unresolved. If Duquesne satisfies all of the obligations set by the FERC, its planned transition date is October 9, 2008.

On March 18, 2008, the PJM Power Providers Group filed a request for emergency clarification regarding whether Duquesne-zone generators (including the Beaver Valley Plant) could participate in PJM’s May 2008 auction for the 2011-2012 RPM delivery year. FirstEnergy and the other Duquesne-zone generators filed responsive pleadings. On April 18, 2008, the FERC issued its Order on Motion for Emergency Clarification, wherein the FERC ruled that although the status of the Duquesne-zone generators will change to “External Resource” upon Duquesne’s exit from PJM, these generators can contract with PJM for the transmission reservations necessary to participate in the May 2008 auction. FirstEnergy has complied with FERC’s order by obtaining executed transmission service agreements for firm point-to-point transmission service for the 2011-2012 delivery year and, as such, FirstEnergy satisfies the criteria to bid the Beaver Valley Plant into the May 2008 RPM auction. Notwithstanding these events, on April 30, 2008 and May 1, 2008, certain members of the PJM Power Providers Group filed further pleadings on these issues. On May 2, 2008, FirstEnergy filed a responsive pleading. FirstEnergy is participating in the May 2008 RPM auction for the 2011-2012 RPM delivery year.

MISO Resource Adequacy Proposal

MISO made a filing on December 28, 2007 that would create an enforceable planning reserve requirement in the MISO tariff for load serving entities such as the Ohio Companies, Penn Power, and FES. This requirement is proposed to become effective for the planning year beginning June 1, 2009. The filing would permit MISO to establish the reserve margin requirement for load serving entities based upon a one day loss of load in ten years standard, unless the state utility regulatory agency establishes a different planning reserve for load serving entities in its state. FirstEnergy generally supports the proposal as it promotes a mechanism that will result in long-term commitments from both load-serving entities and resources, including both generation and demand side resources that are necessary for reliable resource adequacy and planning in the MISO footprint. Comments on the filing were filed on January 28, 2008. The FERC approved MISO’s Resource Adequacy proposal on March 26, 2008. Rehearing requests are pending on the FERC’s March 26 Order. A compliance filing establishing the enforcement mechanism for the reserve margin requirement is due on or before June 25, 2008.

Organized Wholesale Power Markets

On February 21, 2008, the FERC issued a NOPR through which it proposes to adopt new rules that it states will “improve operations in organized electric markets, boost competition and bring additional benefits to consumers.” The proposed rule addresses demand response and market pricing during reserve shortages, long-term power contracting, market-monitoring policies, and responsiveness of RTOs and ISOs to stakeholders and customers. FirstEnergy does not believe that the proposed rule will have a significant impact on its operations. Comments on the NOPR were filed on April 18, 2008.

 
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12.  NEW ACCOUNTING STANDARDS AND INTERPRETATIONS

SFAS 141(R) – “Business Combinations”

In December 2007, the FASB issued SFAS 141(R), which requires the acquiring entity in a business combination to recognize all the assets acquired and liabilities assumed in the transaction; establishes the acquisition-date fair value as the measurement objective for all assets acquired and liabilities assumed; and requires the acquirer to disclose to investors and other users all of the information they need to evaluate and understand the nature and financial effect of the business combination. SFAS 141(R) attempts to reduce the complexity of existing GAAP related to business combinations. The Standard includes both core principles and pertinent application guidance, eliminating the need for numerous EITF issues and other interpretative guidance. SFAS 141(R) will affect business combinations entered into by FirstEnergy that close after January 1, 2009. In addition, the Standard also affects the accounting for changes in tax valuation allowances made after January 1, 2009, that were established as part of a business combination prior to the implementation of this Standard. FirstEnergy is currently evaluating the impact of adopting this Standard on its financial statements.

SFAS 160 - “Noncontrolling Interests in Consolidated Financial Statements – an Amendment of ARB No. 51”

In December 2007, the FASB issued SFAS 160 that establishes accounting and reporting standards for the noncontrolling interest in a subsidiary and for the deconsolidation of a subsidiary. It clarifies that a noncontrolling interest in a subsidiary is an ownership interest in the consolidated entity that should be reported as equity in the consolidated financial statements. This Statement is effective for fiscal years, and interim periods within those fiscal years, beginning on or after December 15, 2008. Early adoption is prohibited. The Statement is not expected to have a material impact on FirstEnergy’s financial statements.

 
SFAS 161 - “Disclosures about Derivative Instruments and Hedging Activities – an Amendment of FASB Statement No. 133”

In March 2008, the FASB issued SFAS 161, which requires enhancements to the current disclosure framework for derivative instruments and hedging activities. The Statement requires that objectives for using derivative instruments be disclosed in terms of underlying risk and accounting designation. This disclosure is intended to better convey the purpose of derivatives use in terms of the risks that the entity is intending to manage. The FASB believes disclosing the fair values of derivative instruments and their gains and losses in a tabular format is designed to provide a more complete picture of the location in an entity’s financial statements of both the derivative positions existing at period end and the effect of using derivatives during the reporting period. Disclosing information about credit-risk-related contingent features is designed to provide financial statement users information on the potential effect on an entity’s liquidity from using derivatives. Finally, this Statement requires cross-referencing within the footnotes, which is intended to help users of financial statements locate important information about derivative instruments. FirstEnergy is currently evaluating the impact of adopting this Standard on its financial statements.

13.  SEGMENT INFORMATION

FirstEnergy has three reportable operating segments: energy delivery services, competitive energy services and Ohio transitional generation services. The “Other” segment primarily consists of telecommunications services. The assets and revenues for the other business operations are below the quantifiable threshold for operating segments for separate disclosure as “reportable operating segments.”

The energy delivery services segment designs, constructs, operates and maintains FirstEnergy's regulated transmission and distribution systems and is responsible for the regulated generation commodity operations of FirstEnergy’s Pennsylvania and New Jersey electric utility subsidiaries. Its revenues are primarily derived from the delivery of electricity, cost recovery of regulatory assets and default service electric generation sales to non-shopping customers in its Pennsylvania and New Jersey franchise areas. Its results reflect the commodity costs of securing electric generation from FES under partial requirements purchased power agreements and from non-affiliated power suppliers as well as the net PJM transmission expenses related to the delivery of that generation load.

The competitive energy services segment supplies electric power to its electric utility affiliates, provides competitive electric sales primarily in Ohio, Pennsylvania, Maryland and Michigan, owns or leases and operates FirstEnergy’s generating facilities and purchases electricity to meet its sales obligations. The segment's net income is primarily derived from the affiliated company PSA sales and the non-affiliated electric generation sales revenues less the related costs of electricity generation, including purchased power and net transmission (including congestion) and ancillary costs charged by PJM and MISO to deliver electricity to the segment’s customers. The segment’s internal revenues represent the affiliated company PSA sales.

 
43

 


The Ohio transitional generation services segment represents the regulated generation commodity operations of FirstEnergy’s Ohio electric utility subsidiaries. Its revenues are primarily derived from electric generation sales to non-shopping customers under the PLR obligations of the Ohio Companies. Its results reflect the purchase of electricity from the competitive energy services segment through full-requirements PSA arrangements, the deferral and amortization of certain fuel costs authorized for recovery by the energy delivery services segment and the net MISO transmission revenues and expenses related to the delivery of generation load. This segment’s total assets consist of accounts receivable for generation revenues from retail customers.

 
Segment Financial Information
                               
               
Ohio
                   
   
Energy
   
Competitive
   
Transitional
                   
   
Delivery
   
Energy
   
Generation
         
Reconciling
       
Three Months Ended
 
Services
   
Services
   
Services
   
Other
   
Adjustments
   
Consolidated
 
   
(In millions)
 
March 31, 2008
                                   
External revenues
  $ 2,212     $ 329     $ 707     $ 40     $ (11 )   $ 3,277  
Internal revenues
    -       776       -       -       (776 )     -  
Total revenues
    2,212       1,105       707       40       (787 )     3,277  
Depreciation and amortization
    255       53       4       -       5       317  
Investment income
    45       (6 )     1       -       (23 )     17  
Net interest charges
    103       27       -       -       41       171  
Income taxes
    119       58       15       14       (19 )     187  
Net income
    179       87       23       22       (35 )     276  
Total assets
    23,211       8,108       257       281       558       32,415  
Total goodwill
    5,582       24       -       -       -       5,606  
Property additions
    255       462       -       12       (18 )     711  
                                                 
March 31, 2007
                                               
External revenues
  $ 2,040     $ 321     $ 619     $ 12     $ (19 )   $ 2,973  
Internal revenues
    -       714       -       -       (714 )     -  
Total revenues
    2,040       1,035       619       12       (733 )     2,973  
Depreciation and amortization
    220       51       (15 )     1       6       263  
Investment income
    70       3       1       -       (41 )     33  
Net interest charges
    107       49       1       2       21       180  
Income taxes
    148       65       15       5       (33 )     200  
Net income
    218       98       24       1       (51 )     290  
Total assets
    23,526       7,089       246       254       675       31,790  
Total goodwill
    5,874       24       -       -       -       5,898  
Property additions
    155       124       -       1       16       296  

 
Reconciling adjustments to segment operating results from internal management reporting to consolidated external financial reporting primarily consist of interest expense related to holding company debt, corporate support services revenues and expenses and elimination of intersegment transactions.

14.  SUPPLEMENTAL GUARANTOR INFORMATION

On July 13, 2007, FGCO completed a sale and leaseback transaction for its 93.825% undivided interest in Bruce Mansfield Unit 1. FES has unconditionally and irrevocably guaranteed all of FGCO’s obligations under each of the leases. The related lessor notes and pass through certificates are not guaranteed by FES or FGCO, but the notes are secured by, among other things, each lessor trust’s undivided interest in Unit 1, rights and interests under the applicable lease and rights and interests under other related agreements, including FES’ lease guaranty.

The consolidating statements of income for the three months ended March 31, 2008 and 2007, consolidating balance sheets as of March 31, 2008 and December 31, 2007 and condensed consolidating statements of cash flows for the three months ended March 31, 2008 and 2007 for FES (parent and guarantor), FGCO and NGC (non-guarantor) are presented below. Investments in wholly owned subsidiaries are accounted for by FES using the equity method. Results of operations for FGCO and NGC are, therefore, reflected in FES’ investment accounts and earnings as if operating lease treatment was achieved. The principal elimination entries eliminate investments in subsidiaries and intercompany balances and transactions and reflect operating lease treatment associated with the 2007 Bruce Mansfield Unit 1 sale and leaseback transaction.

 
44

 




FIRSTENERGY SOLUTIONS CORP.
 
                               
CONSOLIDATING STATEMENTS OF INCOME
 
(Unaudited)
 
                               
For the Three Months Ended March 31, 2008
 
FES
   
FGCO
   
NGC
   
Eliminations
   
Consolidated
 
   
(In thousands)
 
                               
REVENUES
  $ 1,099,848     $ 567,701     $ 325,684     $ (894,117 )   $ 1,099,116  
                                         
EXPENSES:
                                       
Fuel
    2,138       291,239       28,312       -       321,689  
Purchased power from non-affiliates
    206,724       -       -       -       206,724  
Purchased power from affiliates
    891,979       2,138       25,485       (894,117 )     25,485  
Other operating expenses
    37,596       107,167       139,595       12,188       296,546  
Provision for depreciation
    307       26,599       24,194       (1,358 )     49,742  
General taxes
    5,415       11,570       6,212       -       23,197  
Total expenses
    1,144,159       438,713       223,798       (883,287 )     923,383  
                                         
OPERATING INCOME (LOSS)
    (44,311 )     128,988       101,886       (10,830 )     175,733  
                                         
OTHER INCOME (EXPENSE):
                                       
Miscellaneous income (expense), including
                                       
net income from equity investees
    121,725       (1,208 )     (6,537 )     (116,884 )     (2,904 )
Interest expense to affiliates
    (82 )     (5,289 )     (1,839 )     -       (7,210 )
Interest expense - other
    (3,978 )     (25,968 )     (11,018 )     16,429       (24,535 )
Capitalized interest
    21       6,228       414       -       6,663  
Total other income (expense)
    117,686       (26,237 )     (18,980 )     (100,455 )     (27,986 )
                                         
INCOME BEFORE INCOME TAXES
    73,375       102,751       82,906       (111,285 )     147,747  
                                         
INCOME TAXES (BENEFIT)
    (16,609 )     39,285       32,764       2,323       57,763  
                                         
NET INCOME
  $ 89,984     $ 63,466     $ 50,142     $ (113,608 )   $ 89,984  
 
 
 
45

 


FIRSTENERGY SOLUTIONS CORP.
 
                               
CONSOLIDATING STATEMENTS OF INCOME
 
(Unaudited)
 
                               
For the Three Months Ended March 31, 2007
 
FES
   
FGCO
   
NGC
   
Eliminations
   
Consolidated
 
   
(In thousands)
 
                               
REVENUES
  $ 1,019,387     $ 551,355     $ 234,091     $ (786,540 )   $ 1,018,293  
                                         
EXPENSES:
                                       
Fuel
    2,367       201,231       29,937       -       233,535  
Purchased power from non-affiliates
    186,203       2,367       -       (2,367 )     186,203  
Purchased power from affiliates
    784,172       59,069       17,415       (784,173 )     76,483  
Other operating expenses
    51,249       99,095       113,252       -       263,596  
Provision for depreciation
    453       24,936       22,621       -       48,010  
General taxes
    4,934       10,568       6,216       -       21,718  
Total expenses
    1,029,378       397,266       189,441       (786,540 )     829,545  
                                         
OPERATING INCOME (LOSS)
    (9,991 )     154,089       44,650       -       188,748  
                                         
OTHER INCOME (EXPENSE):
                                       
Miscellaneous income (expense), including
                                       
net income from equity investees
    113,948       916       5,200       (100,332 )     19,732  
Interest expense to affiliates
    -       (24,331 )     (5,115 )     -       (29,446 )
Interest expense - other
    (1,385 )     (6,760 )     (9,213 )     -       (17,358 )
Capitalized interest
    5       2,099       1,105       -       3,209  
Total other income (expense)
    112,568       (28,076 )     (8,023 )     (100,332 )     (23,863 )
                                         
INCOME BEFORE INCOME TAXES
    102,577       126,013       36,627       (100,332 )     164,885  
                                         
INCOME TAXES
    73       49,289       13,019       -       62,381  
                                         
NET INCOME
  $ 102,504     $ 76,724     $ 23,608     $ (100,332 )   $ 102,504  

 
 
46

 


FIRSTENERGY SOLUTIONS CORP.
 
                               
CONSOLIDATING BALANCE SHEETS
 
(Unaudited)
 
                               
As of March 31, 2008
 
FES
   
FGCO
   
NGC
   
Eliminations
   
Consolidated
 
   
(In thousands)
 
ASSETS
                             
                               
CURRENT ASSETS:
                             
Cash and cash equivalents
  $ 2     $ -     $ -     $ -     $ 2  
Receivables-
                                       
Customers
    125,116       -       -       -       125,116  
Associated companies
    285,350       231,049       96,852       (295,511 )     317,740  
Other
    1,174       1,050       -               2,224  
Notes receivable from associated companies
    668,376       -       69,011       -       737,387  
Materials and supplies, at average cost
    2,849       264,501       207,275       -       474,625  
Prepayments and other
    107,798       26,208       1,728       -       135,734  
      1,190,665       522,808       374,866       (295,511 )     1,792,828  
                                         
PROPERTY, PLANT AND EQUIPMENT:
                                       
In service
    35,302       5,359,381       3,700,973       (391,896 )     8,703,760  
Less - Accumulated provision for depreciation
    7,810       2,655,103       1,537,747       (168,115 )     4,032,545  
      27,492       2,704,278       2,163,226       (223,781 )     4,671,215  
Construction work in progress
    10,792       881,899       165,389       -       1,058,080  
      38,284       3,586,177       2,328,615       (223,781 )     5,729,295  
                                         
OTHER PROPERTY AND INVESTMENTS:
                                       
Nuclear plant decommissioning trusts
    -       -       1,263,338       -       1,263,338  
Long-term notes receivable from associated companies
    -       -       62,900       -       62,900  
Investment in associated companies
    2,598,022       -       -       (2,598,022 )     -  
Other
    2,529       21,657       202       -       24,388  
      2,600,551       21,657       1,326,440       (2,598,022 )     1,350,626  
                                         
DEFERRED CHARGES AND OTHER ASSETS:
                                       
Accumulated deferred income taxes
    10,518       495,131       -       (248,666 )     256,983  
Lease assignment receivable from associated companies
    -       67,256       -       -       67,256  
Goodwill
    24,248               -       -       24,248  
Property taxes
    -       25,007       22,767       -       47,774  
Pension assets
    3,214       12,856       -       -       16,070  
Unamortized sale and leaseback costs
    -       38,120       -       47,575       85,695  
Other
    18,177       49,393       5,188       (37,939 )     34,819  
      56,157       687,763       27,955       (239,030 )     532,845  
    $ 3,885,657     $ 4,818,405     $ 4,057,876     $ (3,356,344 )   $ 9,405,594  
                                         
LIABILITIES AND CAPITALIZATION
                                       
                                         
CURRENT LIABILITIES:
                                       
Currently payable long-term debt
  $ -     $ 738,087     $ 887,265     $ (16,896 )   $ 1,608,456  
Notes payable-
                                       
Associated companies
    -       885,760       260,199       -       1,145,959  
Other
    700,000       -       -       -       700,000  
Accounts payable-
                                       
Associated companies
    554,844       1,419       119,773       (270,368 )     405,668  
Other
    55,614       130,090       -       -       185,704  
Accrued taxes
    3,378       116,383       47,292       (24,219 )     142,834  
Other
    85,100       107,791       9,731       45,484       248,106  
      1,398,936       1,979,530       1,324,260       (265,999 )     4,436,727  
                                         
CAPITALIZATION:
                                       
Common stockholder's equity
    2,460,215       1,011,907       1,579,614       (2,591,521 )     2,460,215  
Long-term debt and other long-term obligations
    -       1,320,773       62,900       (1,305,717 )     77,956  
      2,460,215       2,332,680       1,642,514       (3,897,238 )     2,538,171  
                                         
NONCURRENT LIABILITIES:
                                       
Deferred gain on sale and leaseback transaction
    -       -       -       1,051,871       1,051,871  
Accumulated deferred income taxes
    -       -       244,978       (244,978 )     -  
Accumulated deferred investment tax credits
    -       35,350       24,619       -       59,969  
Asset retirement obligations
    -       24,947       798,739       -       823,686  
Retirement benefits
    9,332       56,016       -       -       65,348  
Property taxes
    -       25,329       22,766       -       48,095  
Lease market valuation liability
    -       341,881       -       -       341,881  
Other
    17,174       22,672       -       -       39,846  
      26,506       506,195       1,091,102       806,893       2,430,696  
    $ 3,885,657     $ 4,818,405     $ 4,057,876     $ (3,356,344 )   $ 9,405,594  
 
 
 
47

 


FIRSTENERGY SOLUTIONS CORP.
 
                               
CONSOLIDATING BALANCE SHEETS
 
(Unaudited)
 
                               
As of December 31, 2007
 
FES
   
FGCO
   
NGC
   
Eliminations
   
Consolidated
 
   
(In thousands)
 
ASSETS
                             
                               
CURRENT ASSETS:
                             
Cash and cash equivalents
  $ 2     $ -     $ -     $ -     $ 2  
Receivables-
                                       
Customers
    133,846       -       -       -       133,846  
Associated companies
    327,715       237,202       98,238       (286,656 )     376,499  
Other
    2,845       978       -       -       3,823  
Notes receivable from associated companies
    23,772       -       69,012       -       92,784  
Materials and supplies, at average cost
    195       215,986       210,834       -       427,015  
Prepayments and other
    67,981       21,605       2,754       -       92,340  
       556,356       475,771       380,838       (286,656 )     1,126,309  
                                         
PROPERTY, PLANT AND EQUIPMENT:
                                       
In service
    25,513       5,065,373       3,595,964       (392,082 )     8,294,768  
Less - Accumulated provision for depreciation
    7,503       2,553,554       1,497,712       (166,756 )     3,892,013  
      18,010       2,511,819       2,098,252       (225,326 )     4,402,755  
Construction work in progress
    1,176       571,672       188,853       -       761,701  
      19,186       3,083,491       2,287,105       (225,326 )     5,164,456  
                                         
OTHER PROPERTY AND INVESTMENTS:
                                       
Nuclear plant decommissioning trusts
    -       -       1,332,913       -       1,332,913  
Long-term notes receivable from associated  companies
    -       -       62,900       -       62,900  
Investment in associated companies
    2,516,838       -       -       (2,516,838 )     -  
Other
    2,732       37,071       201       -       40,004  
      2,519,570       37,071       1,396,014       (2,516,838 )     1,435,817  
                                         
DEFERRED CHARGES AND OTHER ASSETS:
                                       
Accumulated deferred income taxes
    16,978       522,216       -       (262,271 )     276,923  
Lease assignment receivable from associated companies
    -       215,258       -       -       215,258  
Goodwill
    24,248       -       -       -       24,248  
Property taxes
    -       25,007       22,767       -       47,774  
Pension asset
    3,217       13,506       -       -       16,723  
Unamortized sale and leaseback costs
    -       27,597       -       43,206       70,803  
Other
    22,956       52,971       6,159       (38,133 )     43,953  
      67,399       856,555       28,926       (257,198 )     695,682  
TOTAL ASSETS
  $ 3,162,511     $ 4,452,888     $ 4,092,883     $ (3,286,018 )   $ 8,422,264  
                                         
LIABILITIES AND CAPITALIZATION
                                       
CURRENT LIABILITIES:
                                       
Currently payable long-term debt
  $ -     $ 596,827     $ 861,265     $ (16,896 )   $ 1,441,196  
Short-term borrowings-
                                       
Associated companies
    -       238,786       25,278       -       264,064  
Other
    300,000       -       -       -       300,000  
Accounts payable-
                                       
Associated companies
    287,029       175,965       268,926       (286,656 )     445,264  
Other
    56,194       120,927       -       -       177,121  
Accrued taxes
    18,831       125,227       28,229       (836 )     171,451  
Other
    57,705       131,404       11,972       36,725       237,806  
      719,759       1,389,136       1,195,670       (267,663 )     3,036,902  
                                         
CAPITALIZATION:
                                       
Common stockholder's equity
    2,414,231       951,542       1,562,069       (2,513,611 )     2,414,231  
Long-term debt and other long-term obligations
    -       1,597,028       242,400       (1,305,716 )     533,712  
      2,414,231       2,548,570       1,804,469       (3,819,327 )     2,947,943  
                                         
NONCURRENT LIABILITIES:
                                       
Deferred gain on sale and leaseback transaction
    -       -       -       1,060,119       1,060,119  
Accumulated deferred income taxes
    -       -       259,147       (259,147 )     -  
Accumulated deferred investment tax credits
    -       36,054       25,062       -       61,116  
Asset retirement obligations
    -       24,346       785,768       -       810,114  
Retirement benefits
    8,721       54,415       -       -       63,136  
Property taxes
    -       25,328       22,767       -       48,095  
Lease market valuation liability
    -       353,210       -       -       353,210  
Other
    19,800       21,829       -       -       41,629  
      28,521       515,182       1,092,744       800,972       2,437,419  
TOTAL LIABILITIES AND CAPITALIZATION
  $ 3,162,511     $ 4,452,888     $ 4,092,883     $ (3,286,018 )   $ 8,422,264  

 
 
48

 
 

FIRSTENERGY SOLUTIONS CORP.
 
                               
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
 
(Unaudited)
 
                               
For the Three Months Ended March 31, 2008
 
FES
   
FGCO
   
NGC
   
Eliminations
   
Consolidated
 
   
(In thousands)
 
                               
NET CASH PROVIDED FROM (USED FOR)
                             
OPERATING ACTIVITIES
  $ 273,827     $ (122,171 )   $ 8,108     $ 188     $ 159,952  
                                         
CASH FLOWS FROM FINANCING ACTIVITIES:
                                       
New Financing-
                                       
Short-term borrowings, net
    400,000       646,975       234,921       -       1,281,896  
Redemptions and Repayments-
                                       
Long-term debt
    -       (135,063 )     (153,540 )     -       (288,603 )
Common stock dividend payments
    (10,000 )     -       -       -       (10,000 )
     Net cash provided from financing activities
    390,000       511,912       81,381       -       983,293  
                                         
CASH FLOWS FROM INVESTING ACTIVITIES:
                                       
Property additions
    (19,406 )     (375,391 )     (81,545 )     (187 )     (476,529 )
Proceeds from asset sales
    -       5,088       -       -       5,088  
Sales of investment securities held in trusts
    -       -       173,123       -       173,123  
Purchases of investment securities held in trusts
    -       -       (181,079 )     -       (181,079 )
Loans to associated companies, net
    (644,604 )     -       -       -       (644,604 )
Other
    183       (19,438 )     12       (1 )     (19,244 )
   Net cash used for investing activities
    (663,827 )     (389,741 )     (89,489 )     (188 )     (1,143,245 )
                                         
Net change in cash and cash equivalents
    -       -       -       -       -  
Cash and cash equivalents at beginning of period
    2       -       -       -       2  
Cash and cash equivalents at end of period
  $ 2     $ -     $ -     $ -     $ 2  
 

 
49

 


FIRSTENERGY SOLUTIONS CORP.
 
                               
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
 
(Unaudited)
 
                               
For the Three Months Ended March 31, 2007
 
FES
   
FGCO
   
NGC
   
Eliminations
   
Consolidated
 
   
(In thousands)
 
                               
NET CASH PROVIDED FROM
                             
OPERATING ACTIVITIES
  $ 65,870     $ 55,003     $ 177,456     $ -     $ 298,329  
                                         
CASH FLOWS FROM FINANCING ACTIVITIES:
                                       
New Financing-
                                       
Equity contribution from parent
    700,000       700,000       -       (700,000 )     700,000  
Short-term borrowings, net
    250,000       -       -       (52,269 )     197,731  
Redemptions and Repayments-
                                       
Long-term debt
    -       (616,728 )     (128,716 )     -       (745,444 )
Short-term borrowings, net
    -       (52,269 )     -       52,269       -  
      Net cash provided from (used for) financing activities
    950,000       31,003       (128,716 )     (700,000 )     152,287  
                                         
CASH FLOWS FROM INVESTING ACTIVITIES:
                                       
Property additions
    (214 )     (81,400 )     (35,892 )     -       (117,506 )
Sales of investment securities held in trusts
    -       -       178,632       -       178,632  
Purchases of investment securities held in trusts
    -       -       (188,076 )     -       (188,076 )
Loans to associated companies, net
    (316,003 )     -       (3,895 )     -       (319,898 )
Investment in subsidiary
    (700,000 )     -       -       700,000       -  
Other
    347       (4,606 )     491       -       (3,768 )
   Net cash used for investing activities
    (1,015,870 )     (86,006 )     (48,740 )     700,000       (450,616 )
                                         
Net change in cash and cash equivalents
    -       -       -       -       -  
Cash and cash equivalents at beginning of period
    2       -       -       -       2  
Cash and cash equivalents at end of period
  $ 2     $ -     $ -     $ -     $ 2  

  
 
50

 


ITEM 4T. CONTROLS AND PROCEDURES – OE, CEI, TE AND PENELEC (Restated)

(a)           EVALUATION OF DISCLOSURE CONTROLS AND PROCEDURES

In the original Form 10-Q for the first quarter of 2008, each registrant’s chief executive officer and chief financial officer concluded that, as of the end of the period covered by that report, the applicable registrant's disclosure controls and procedures were effective as of March 31, 2008. Subsequent to the restatement of the respective registrants’ Consolidated Statements of Cash Flows discussed in the revised Note 1 to the Combined Notes to Consolidated Financial Statements included in the Form 10-Q/A, each registrant's chief executive officer and chief financial officer performed an updated review and evaluated such registrant's disclosure controls and procedures. Based upon that updated evaluation and as a result of the material weakness in the internal controls over the preparation and review of the Consolidated Statement of Cash Flows discussed below, those officers concluded that, as of the end of the period covered by this report, the applicable registrant's disclosure controls and procedures were ineffective as of March 31, 2008.

The term disclosure controls and procedures means controls and other procedures of a registrant that are designed to ensure that information required to be disclosed by the registrant in the reports that it files or submits under the Securities Exchange Act of 1934 (15 U.S.C. 78a et seq.) is recorded, processed, summarized and reported, within the time periods specified in the Securities and Exchange Commission's rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by an issuer in the reports that it files or submits under that Act is accumulated and communicated to the registrant's management, including its principal executive and principal financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.

As reported in this Form 10-Q/A, each registrant has amended its original Form 10-Q for the first quarter of 2008 to restate its Consolidated Statements of Cash Flows for the three months ended March 31, 2008, to correct common stock dividend payments reported in cash flows from financing activities. The Consolidated Statements of Cash Flows for each registrant, as originally filed, erroneously did not reflect the payment of common stock dividends in the first quarter of 2008, which were declared in the third quarter of 2007. The corrections resulted in a corresponding change in operating liabilities - accounts payable, included in cash flows from operating activities.

A material weakness is a deficiency, or a combination of deficiencies in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of the company's annual or interim financial statements will not be prevented or detected on a timely basis.
 
The restatement described above resulted from a material weakness in the internal controls over one aspect of the preparation and review of the Consolidated Statements of Cash Flows. Specifically, the registrants did not have a control that was designed to ensure that declared but unpaid dividends to the registrants’ parent were not reported as cash used for financing activities. This control deficiency resulted in a material misstatement of the registrants’ interim and annual consolidated financial statements. Accordingly, management determined that this control deficiency constitutes a material weakness. The registrants modified their internal controls over the preparation and review of their Consolidated Statements of Cash Flows during the fourth quarter of 2008. Management has implemented a process to segregate dividend declarations with payments applicable to future reporting periods in a unique general ledger account in order to distinguish associated company dividends payable from other associated company accounts payable. Management believes that this process enhances the existing internal controls over financial reporting and remediated the material weakness discussed above for each of the registrants.

(b)           CHANGES IN INTERNAL CONTROLS

During the quarter ended March 31, 2008, there were no changes in the registrants' internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, the registrants' internal control over financial reporting.


 
51

 

PART II. OTHER INFORMATION

ITEM 6.   EXHIBITS

Exhibit
Number
     
     
         
OE
   
 
15
Letter from independent registered public accounting firm
 
 
31.1
Certification of chief executive officer, as adopted pursuant to Rule 13a-14(a)
 
 
31.2
Certification of chief financial officer, as adopted pursuant to Rule 13a-14(a)
 
 
32
Certification of chief executive officer and chief financial officer, pursuant to 18 U.S.C. Section 1350
 
CEI
   
  15
Letter from independent registered public accounting firm
 
 
31.1
Certification of chief executive officer, as adopted pursuant to Rule 13a-14(a)
 
 
31.2
Certification of chief financial officer, as adopted pursuant to Rule 13a-14(a)
 
 
32
Certification of chief executive officer and chief financial officer, pursuant to 18 U.S.C. Section 1350
 
TE
   
  15
Letter from independent registered public accounting firm
 
 
31.1
Certification of chief executive officer, as adopted pursuant to Rule 13a-14(a)
 
 
31.2
Certification of chief financial officer, as adopted pursuant to Rule 13a-14(a)
 
 
32
Certification of chief executive officer and chief financial officer, pursuant to 18 U.S.C. Section 1350
 
Penelec
 
 
15
Letter from independent registered public accounting firm
 
31.1
Certification of chief executive officer, as adopted pursuant to Rule 13a-14(a)
 
31.2
Certification of chief financial officer, as adopted pursuant to Rule 13a-14(a)
 
32
Certification of chief executive officer and chief financial officer, pursuant to 18 U.S.C. Section 1350

 
Pursuant to reporting requirements of respective financings, OE and Penelec are required to file fixed charge ratios as an exhibit to this Form 10-Q. Pursuant to paragraph (b)(4)(iii)(A) of Item 601 of Regulation S-K, neither OE, CEI, TE nor Penelec have filed as an exhibit to this Form 10-Q any instrument with respect to long-term debt if the respective total amount of securities authorized thereunder does not exceed 10% of its respective total assets, but each hereby agrees to furnish to the SEC on request any such documents.

 
52

 

SIGNATURES



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


November 25, 2008





 
OHIO EDISON COMPANY
 
Registrant
   
 
THE CLEVELAND ELECTRIC
 
ILLUMINATING COMPANY
 
Registrant
   
 
THE TOLEDO EDISON COMPANY
 
Registrant
   
 
PENNSYLVANIA ELECTRIC COMPANY
 
Registrant



 
/s/  Harvey L. Wagner
 
Harvey L. Wagner
 
Vice President and Controller





 
53