EX-99.2 3 ex99_2.htm CONSOLIDATED REPORT TO THE FINANCIAL COMMUNITY, DATED FEB. 20, 2007 Consolidated Report to the Financial Community, dated Feb. 20, 2007
 
EXHIBIT 99.2

Consolidated Report to the Financial Community                            
Fourth Quarter 2006    
(Released February 20, 2007) (Unaudited)                        
 
           
 
 HIGHLIGHTS
    After-Tax EPS Variance Analysis
 4th Qtr.
  
       4Q 2005 Basic EPS - GAAP Basis
           $ 0.58
 
 §  Normalized non-GAAP* earnings, excluding       Unusual Items - 2005 
              0.10
  
   unusual items, were $0.84 per share for the      Cumulative Effect of an Accounting Change
$0.09 
 
   fourth quarter of 2006, compared with $0.77    4Q 2005 Normalized Earnings - Non-GAAP Basis*
            $0.77
  
   per share for the fourth quarter of 2005.       Distribution Deliveries
(0.05)
 
   GAAP earnings were $0.85 per share       Generation Revenues
         (0.03)         
 
   compared with $0.58 per share in the        Fuel & Purchased Power            
 (0.12) 
 
   fourth quarter of 2005.      Nuclear O&M
 (.08)
  
         Postretirement Health Care Costs
0 .01
 
          Ohio Regulatory Changes
 
  
               - Transition Cost Amortization 
 0.20 
  
 §  Normalized non-GAAP earnings for 2006,            - Deferred Distribution Costs 
 0.06 
 
   excluding unusual items,were $3.88 per            - Deferred Fuel Costs                    0.04  
   share, exceeding the top of our earnings            - Rate Stabilization Charge Discount 
(0.07)
  
   guidance of $3.75 to $3.85 per share.      Deferred Transmission Costs - PA
             0.09
  
   This also compares favorably with 2005       Net MISO / PJM Transmission Costs 
 0.07 
 
   normalized, non-GAAP earnings of $3.00      Depreciation             (0.01)  
   earnings were $3.84 per share, compared      Financing Costs
(0.05)
  
   with $2.62 per share in 2005.       Reduced Common Shares
    0.02  
  
          Other             (0.01)  
       4Q 2006 Normalized Earnings - Non-GAAP Basis*             $0.84  
        Unusual Items - 2006               0.01  
       4Q 2006 Basic EPS - GAAP Basis  
   $0.85  
 
           
 
4Q 2006 Resultsvs. 4Q 2005
 
 §
 Electric distribution deliveries 2%, primarily due to milder weather.  Heating-degree-days were 15% lower than the same period last year and 13% below normal. Residential and industrial deliveries both decreased 3%, while commercial deliveries declined 1%.  Lower distribution revenue reduced earnings by $0.05 per share.
 
 §
 Total electric generation sales were flat, as a 5% increase in retail sales offset an 18% reduction in wholesale sales.  The change in generation sales mix resulted from returning Ohio shopping customers. Generation revenues, excluding JCP&L, reduced earnings $0.03 per share due to lower wholesale market prices.
 
 §
 Higher fuel expenses reduced earnings by $0.05 per share due to higher fossil generation output and increased coal prices.  Increased purchased power reduced earnings by $0.07 per share, primarily as a result of the refueling outage at Beaver Valley Unit 2.
 
 §
Nuclear operating expenses decreased earnings by $0.08 per share, primarily due to the refueling of Beaver Valley Unit 2, with no comparable outage in the fourth quarter of 2005.
 
 §
Postretirement health care costs increased earnings by $0.01 per share largely due to design changes that become effective in 2008.
 
 
1
 
 
 §
The impact of several elements of the Ohio rate plans that became effective in 2006 increased earnings by $0.23 per share. The major driver of this improvement was a $0.20 per share reduction in transition cost amortization. Other changes included the deferral of $0.06 per share of costs related to distribution reliability spending and the deferral of $0.04 per share of incremental fuel expense, partially offset by a $0.07 per share earnings reduction related to the Rate Stabilization Charge discount provided to shopping customers. 
 
 §
The deferral of incremental transmission charges for Metropolitan Edison and Pennsylvania Electric increased earnings by $0.09 per share. In January 2007, the Pennsylvania Public Utility Commission authorized recovery of the 2006 deferred charges over a ten-year period and established a Transmission Service Charge Rider to begin collecting the incremental transmission charges on a going-forward basis.
 
 §
 Net MISO/PJM transmission costs increased earnings by $0.07 per share, primarily due to lower MISO expenses and lower congestion costs in the PJM market.
 
 §
Total financing costs increased by $0.05 per share, primarily attributable to an $11 million pre-tax loss on reqcquired debt, a $5 million after-tax charge related to the optional redemption of $80 million of subsidiaries' preferred stock, and a higher level of outstanding short-term borrowings related to funding our accelerated share repurchase program.
 
 §
The reduction in shares outstanding, resulting from the accelerated share repurchase of 10.6 million shares in August 2006, enhanced earnings per share by $0.02 compared with the fourth quarter of 2005.
 
 §
 During the quarter, we recognized a net benefit of $0.01 per share from the gain on the sale of non-core assets, partially offset by the impairment of securities held in trust for future nuclear decommissioning activities.
 
2007 Earnings Guidance
 
 §
Normalized non-GAAP earnings guidance for 2007, excluding unusual items, is $4.05 to $4.25 per share. Our estimate for the quarterly pattern of our 2007 earnings guidance is:
 
 1st Quarter: 20%  2nd Quarter: 25%  3rd Quarter: 32%  4th Quarter: 23% 
       
* The 2006 GAAP to non-GAAP reconciliation statements can be found on pages 10 and 11 of this report and are available on the Investor Information section of FirstEnergy Corp.'s website at www.firstenergycorp.com/ir. The 2005 GAAP to non-GAAP reconciliation statements are also available on FirstEnergy Corp.'s website.
 
 
For additional information, please contact:
 
Ronald E. Seeholzer
Kurt E. Turosky
Rey Y. Jimenez
Vice President, Investor Relations
Director, Investor Relations
Principal, Investor Relations
(330) 384-5783
(330) 384-5500
(330) 761-4239
 
 
2
FirstEnergy Corp.
Consolidated Statements of Income
(Unaudited)
(In millions, except for per share amounts)
 
 
  
Three Months Ended December 31,
        Twelve Months Ended December 31,
 
 
 
2006
 
2005
 
Change
 
2006
 
2005
 
Change
 
Revenues
 
 
 
 
 
 
 
 
 
 
 
 
(1)
Electric sales
 
$
2,492
 
$
2,514
 
$
(22
)
$
10,671
 
$
10,546
 
$
125
 
(2)
FE Facilities
 
 
- 
 
 
21
 
 
(21
)
 
48 
 
 
77 
 
 
(29
)
(3)
Other
 
 
188
 
 
186
 
 
2
 
 
782 
 
 
735 
 
 
47
 
(4)
Total Revenues
 
 
2,680 
 
 
2,721 
 
 
(41
)
 
11,501 
 
 
11,358 
 
 
143
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
 
Expenses 
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
(5)
Fuel
 
 
283 
 
 
269 
 
 
14 
 
 
1,212 
 
 
1,118 
 
 
94 
 
(6)
Purchased power
 
 
664 
 
 
627 
 
 
37 
 
 
3,041 
 
 
2,893 
 
 
148 
 
(7)
Other operating expenses
 
 
735
 
 
790 
 
 
(55
)
 
2,924 
 
 
3,028 
 
 
(104
)
(8)
FE Facilities
 
 
- 
 
 
20 
 
 
(20
)
 
41 
 
 
75 
 
 
(34
)
(9)
Provision for depreciation
 
 
151
 
 
143
 
 
8
 
 
596 
 
 
588 
 
 
8 
 
(10)
Amortization of regulatory assets
 
 
197 
 
 
299 
 
 
(102
)
 
861 
 
 
1,281 
 
 
(420
)
(11)
Deferral of new regulatory assets 
 
 
(121
)
 
(100
)
 
(21
)
 
(500
)
 
(405
)
 
(95
)
(12)
General taxes
 
 
167
 
 
172
 
 
(5
)
 
720
 
 
713 
 
 
7 
 
(13)
Total Expenses
 
 
2,076
 
 
2,220
 
 
(144
)
 
8,895 
 
 
9,291 
 
 
(396
)
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
(14)
Operating Income
 
 
604
 
 
501 
 
 
103 
 
 
2,606 
 
 
2,067 
 
 
539 
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
 
Other Income (Expense) 
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
(15)
Investment income
 
 
29 
 
 
46 
 
 
(17
)
 
149 
 
 
217 
 
 
(68
)
(16)
Interest expense
 
 
(193
)
 
(172
)
 
(21
)
 
(721
)
 
(660
)
 
(61
)
(17)
Capitalized interest
 
 
5 
 
 
7
 
 
(2 
)
 
26
 
 
19
 
 
7 
 
(18)
Subsidiaries' preferred stock dividends
 
 
(1
)
 
(3
)
 
2 
 
 
(7
)
 
(15
)
 
8 
 
(19)
Total Other Income (Expense)
 
 
(160
)
 
(122
)
 
(38
)
 
(553
)
 
(439
)
 
(114
)
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
(20)
Income From Continuing Operations
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
 
Before Income Taxes
 
 
444 
 
 
379 
 
 
65 
 
 
2,053 
 
 
1,628 
 
 
425 
 
(21)
Income taxes
 
 
170 
 
 
153 
 
 
17 
 
 
795 
 
 
749 
 
 
46 
 
(22)
Income From Continuing Operations
 
 
274 
 
 
226 
 
 
48 
 
 
1,258 
 
 
879 
 
 
379
 
(23)
Discontinued operations
 
 
-
 
 
(6
)
 
6 
 
 
(4 
)
 
12 
 
 
(16
)
(24)
    Cumulative effect of a change in
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
   accounting principle 
 
 
 - 
 
 
(30
)
 
 30 
 
 
 - 
 
 
 (30 
)
 
 30 
 
(25)
Net Income 
 
$
274
 
$
190
 
$
84
 
$
1,254
 
$
861
 
$
393
 
 
 
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
 
  
 
 
Basic Earnings Per Common Share:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
(26)
Income from continuing operations
 
$
0.85
 
$
0.69
 
$
0.16
 
$
3.85
 
$
2.68
 
$
1.17
 
(27)
Discontinued operations
 
 
-
 
 
(0.02
)
 
0.02
 
 
(0.01
)
 
0.03
 
 
(0.04
)
(28)
    Cumulative effect of a change in
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
     accounting principle
 
 
 -
 
 
 (0.09
)
 
 0.09
 
 
 -
 
 
 (0.09
)
 
 0.09
 
(29)
 Basic Earnings Per Common Share
 
$
0.85
 
$
0.58
 
$
0.27
 
$
3.84
 
$
2.62
 
$
1.22
 
 (30)  Weighted Average Number of                                      
   Basic Shares Outstanding     318     328     (10 )   324     328     (4 )
                                         
   Diluted Earnings Per Common Share:                                      
 (31)    Income from continuing operations   $ 0.84   $ 0.69   $ 0.15   $ 3.82   $ 2.67   $ 1.15  
 (32)   Discontinued operations     -     (0.02 )   0.02     (0.01 )  0.03     (0.04 )
 (33)
 Cumulative effect of a change in
 accounting principle
     -     (0.09 )   0.09     -     (0.09 )   0.09  
 (34) Diluted Earnings Per Common Share    $ 0.84    $ 0.58    $ 0.26   $ 3.81    $ 2.61    $ 1.20  
 (35)
Weighted Average Number of
Diluted Shares Outstanding
     321     330     (9 )   327     330     (3 )
 
 
 
3

 
FirstEnergy Corp.
Consolidated Income Segments
(Unaudited)
(In millions)

  
 
                              
          
 
       
      Three Months Ended March 31, 2006
    
              
Power
               
              
Supply
               
          
Regulated
  
Management
  
 
  
Reconciling 
  
 
    
          
Services
  
Services
  
Other (a)
  
Adjustments (b)
  
Consolidated
  
 
   
Revenues
                           
 
(1
)
   Electric sales
      
$
878
  
$
1,614
  
$
-
  
$
-
  
$
2,492
  
 
 
  
 
(2
)
    FE Facilities 
        
-
   
-
   
- 
    
-
   
-
   
 
  
 
(3
)
    Other 
        
145 
    
52
    
13 
    
(22)
    
188
 
  
 
  
 
(4
)
    Internal revenues 
        
-
    
-
    
-
    
-
   
-
 
  
 
  
 
(5
)
Total Revenues
        
1,023
   
1,666
   
13 
    
(22)
    
2,680
 
  
 
  
                                                 
     
Expenses
                                          
 
(6
)
    Fuel
        
-
   
283
   
-
   
-
   
283
    
 
  
 
(7
)
    Purchased power
        
-
   
664
   
-
   
-
   
664
    
 
  
 
(8
)
    Other operating expenses 
        
283
    
 451
    
-
    
1 
    
735
 
  
 
  
 
(9
)
    FE Facilities 
        
-
    
- 
    
-
    
- 
    
-
   
 
  
 
(10
)
    Provision for depreciation 
        
96
    
47
    
1 
    
7
    
151
   
 
  
 
(11
)
    Amortization of regulatory assets 
        
192
    
5
    
-
    
-
   
197
    
 
  
 
(12
)
    Deferral of new regulatory assets 
        
(53
)
  
(68
)
  
-
    
-
   
(121
 )  
 
 
 
(13
)
    General taxes 
        
123
   
44
    
(3
 )   
3 
    
167 
    
 
  
 
(14
)
Total Expenses
        
641
    
1,426
   
(2
 )   
11
   
2,076 
    
 
  
                                                 
 
(15
)
Operating Income
        
382 
    
240
    
15
 
  
(33
 )   
604
 
  
 
  
                                                 
     
Other Income (Expense)
                                          
 
(16
)
   Investment income
        
66
    
-
    
-
   
(37
 )  
29
    
 
  
 
(17
)
    Interest expense 
        
(115
)
  
(59
)
  
(1
 )  
(18
)
  
(193
)
  
 
 
 
(18
)
   Capitalized interest
        
2
    
3
    
-
   
-
   
5
    
 
  
 
(19
)
    Subsidiaries' preferred stock dividends
        
(6
)
  
-
   
-
   
5
    
(1
 )   
 
 
 
(20
)
Total Other Income (Expense)
 
      
(53
)
  
(56
)
  
(1)
    
(50
)
  
(160
)
  
 
 
  (21 )
Income From Continuing Operations
 
       329     184     14     (83 )   444        
     
  Before Income Taxes
                                          
 
(22
)
    Income taxes
        
133
    
73
    
(3
 )   
(33
)
  
170
 
  
 
  
  (23 )
Income From Continuing Operations
         196     111     17     (50 )   274        
 
(24
)
  Discontinued operations
        
-
   
-
   
-
   
-
   
-
   
 
  
 
(25
 		 )
Cumulative effect of a change in
  accounting principle
         -     -     -     -     -        
 
(26
 )
Net Income
      
$
196
  
$
111
  
$
17
 
$
(50
 ) 
$
274
 
 
 
  
                                                 
                                                 
 
(a)  Primarily consists of telecommunications services.                    
  
 
(b)  Reconciling adjustments to segment operating results from internal management reporting to consolidated external financial reporting primarily 
       consists of interest expense related to holding company debt, corporate support services revenues and expenses, fuel marketing revenues which are 
       reflected as reductions to expenses for internal management reporting purposes and elimination of intersegment transactions.                         
  
 
 
4
 
FirstEnergy Corp.
Consolidated Income Segments
(Unaudited)
(In millions)
 
                              
          
 
       
      Three Months Ended December 31, 2005
    
              
Power
               
              
Supply
               
          
Regulated
  
Management
  
 
  
Reconciling 
  
 
    
          
Services
  
Services
  
Other (a)
  
Adjustments (b)
  
Consolidated
  
 
   
Revenues
                           
 
(1
)
   Electric sales
      
$
1,073
  
$
1,441
  
$
-
  
$
-
  
$
2,514
  
 
 
  
 
(2
)
    FE Facilities 
        
-
   
-
   
21 
    
-
   
21 
    
 
  
 
(3
)
    Other 
        
128 
    
39 
    
14 
    
5
    
186
 
  
 
  
 
(4
)
    Internal revenues 
        
33 
    
- 
    
- 
    
  (33)
    
-
 
  
 
  
 
(5
)
Total Revenues
        
1,234
   
1,480
   
35 
    
(28)
    
2,721
 
  
 
  
                                                 
     
Expenses
                                          
 
(6
)
    Fuel
        
-
   
269
    
-
   
-
   
269 
    
 
  
 
(7
)
    Purchased power
        
-
   
627
    
-
   
-
   
627 
    
 
  
 
(8
)
    Other operating expenses 
        
257 
    
 510
    
12 
    
11 
    
790
 
  
 
  
 
(9
)
    FE Facilities 
        
- 
    
- 
    
20 
    
- 
    
20
    
 
  
 
(10
)
    Provision for depreciation 
        
118 
    
19 
    
- 
    
6 
    
143 
    
 
  
 
(11
)
    Amortization of regulatory assets 
        
299 
    
- 
    
- 
    
-
   
299
    
 
  
 
(12
)
    Deferral of new regulatory assets 
        
(61
)
  
(39
)
  
- 
    
-
   
(100
 )  
 
 
 
(13
)
    General taxes 
        
138
   
31 
    
-
    
3 
    
172 
    
 
  
 
(14
)
Total Expenses
        
751 
    
1,417
   
32 
    
20 
    
2,220 
    
 
  
                                                 
 
(15
)
Operating Income
        
483 
    
63 
    
3
 
  
(48)
    
501
 
  
 
  
                                                 
     
Other Income (Expense)
                                          
 
(16
)
   Investment income
        
46 
    
- 
    
-
   
-
    
46 
    
 
  
 
(17
)
    Interest expense 
        
(107)
 
  
(26)
 
  
(2)
    
(37)
 
  
(172
)
  
 
 
 
(18
)
   Capitalized interest
        
5 
    
2 
    
-
   
-
   
7 
    
 
  
 
(19
)
    Subsidiaries' preferred stock dividends
        
(3)
 
  
-
   
-
   
- 
    
(3
 )  
 
 
 
(20
)
Total Other Income (Expense)
 
      
(59)
 
  
(24)
 
  
(2)
    
(37
)
  
(122
)
  
 
 
  (21 )
Income From Continuing Operations
                                          
     
  Before Income Taxes 
        424     39     1     (85)     379        
 
(22
)
    Income taxes
        
170
    
16
    
(2)
    
(31)
 
  
153
 
  
 
  
  (23 )
Income From Continuing Operations
         254     23     3     (54)     226        
 
(24
)
    Discontinued operations
        
-
   
-
   
(6)
    
-
   
(6
 )  
 
  
 
(25
 		 )
Cumulative effect of a change in
  accounting principle
         (21)     (9)     -      0     (30 )      
 
(26
 )
Net Income
      
$
233
  
$
14
  
$
(3)
 
$
(54)
  
$
190
 
 
 
  
                                                 
                                                 
 
(a)  Other consists of telecommunications services and non-core businesses whose divestitures were completed in 2006 (FE Facilities and MYR).                    
  
 
(b)  Reconciling adjustments to segment operating results from internal management reporting to consolidated external financial reporting primarily 
       consists of interest expense related to holding company debt, corporate support services revenues and expenses, fuel marketing revenues which are 
       reflected as reductions to expenses for internal management reporting purposes and elimination of intersegment transactions.                         
  
 
 
5
 
FirstEnergy Corp.
Consolidated Income Segments
(Unaudited)
(In millions)
 
                              
          
 
             Three Months Ended December 31, 2006 vs. Three Months Ended December 31, 2005  
              
Power
               
              
Supply
               
          
Regulated
  
Management
  
 
  
Reconciling 
  
 
    
          
Services
  
Services
  
Other (a)
  
Adjustments (b)
  
Consolidated
  
 
   
Revenues
                           
 
(1
)
   Electric sales
      
$
(195)
  
$
173
  
$
-
  
$
-
  
$
(22)
  
 
 
  
 
(2
)
    FE Facilities 
        
-
   
-
   
(21)
    
-
   
(21)
    
 
  
 
(3
)
    Other 
        
17
    
13 
    
(1)
    
(27)
    
2
 
  
 
  
 
(4
)
    Internal revenues 
        
(33)
    
- 
    
- 
    
  33
    
-
 
  
 
  
 
(5
)
Total Revenues
        
(211)
    
186
    
(22)
    
6
    
(41)
 
  
 
  
                                                 
     
Expenses
                                          
 
(6
)
    Fuel
        
-
   
14
    
-
   
-
   
14
    
 
  
 
(7
)
    Purchased power
        
-
   
37
    
-
   
-
   
37
    
 
  
 
(8
)
    Other operating expenses 
        
26
    
 (59)
    
(12)
    
(10)
    
(55)
 
  
 
  
 
(9
)
    FE Facilities 
        
- 
    
- 
    
(20)
    
- 
    
(20)
    
 
  
 
(10
)
    Provision for depreciation 
        
(22)
    
28 
    
1 
    
1 
    
8
    
 
  
 
(11
)
    Amortization of regulatory assets 
        
(107)
    
5 
    
- 
    
-
   
(102)
    
 
  
 
(12
)
    Deferral of new regulatory assets 
        
8
 
  
(29)
 
  
- 
    
-
   
(21)
    
 
 
 
(13
)
    General taxes 
        
(15)
    
13
    
(3)
    
- 
    
(5)
    
 
  
 
(14
)
Total Expenses
        
(110)
    
9 
    
(34)
    
(9)
    
(144)
    
 
  
                                                 
 
(15
)
Operating Income
        
(101)
    
177
    
12
 
  
15
    
103
 
  
 
  
                                                 
     
Other Income (Expense)
                                          
 
(16
)
   Investment income
        
20
    
- 
    
-
   
(37)
    
(17)
    
 
  
 
(17
)
    Interest expense 
        
(8)
 
  
(33)
 
  
1
    
19
 
  
(21)
 
  
 
 
 
(18
)
   Capitalized interest
        
(3)
    
1
    
-
   
-
   
(2)
    
 
  
 
(19
)
    Subsidiaries' preferred stock dividends
        
(3)
 
  
-
   
-
   
5 
    
2
    
 
 
 
(20
)
Total Other Income (Expense)
 
      
6
 
  
(32)
 
  
1
    
(13)
 
  
(38)
 
  
 
 
  (21 )
Income From Continuing Operations 
                                          
     
   Before Income Taxes
         (95)     145     13     2     65        
 
(22
)
    Income taxes
        
(37)
    
57
    
(1)
    
(2)
 
  
17
 
  
 
  
  (23  )
Income From Continuing Operations
         (58)     88     14     4     48        
 
(24
)
    Discontinued operations
        
-
   
-
   
6
    
-
   
6
    
 
  
 
(25
 		  )
Cumulative effect of a change in
  accounting principle
         21     9     -      (0)     30        
 
(26
 )
Net Income
      
$
(37)
  
$
97
  
$
20
 
$
4
  
$
84
 
 
 
  
                                                 
                                                 
 
(a)  Other consists of telecommunications services and non-core businesses whose divestitures were completed in 2006 (FE Facilities and 
     MYR.)                     
 
(b)  Reconciling adjustments to segment operating results from internal management reporting to consolidated external financial reporting primarily 
       consists of interest expense related to holding company debt, corporate support services revenues and expenses, fuel marketing revenues which are 
       reflected as reductions to expenses for internal management reporting purposes and elimination of intersegment transactions.                         
  
 
 
 
6
FirstEnergy Corp.
Financial Statements
(Unaudited)
(In millions)

Condensed Consolidated Balance Sheet
  
 
  
 
  
 
  
 
  
 
  
 
  
As of
Dec. 31, 2006
  
As of
Dec. 31, 2005
  
Assets
  
 
  
 
  
Current Assets:
  
 
  
 
  
Cash and cash equivalents
  
$
90
  
$
64
  
Receivables
    
1,267
   
1,498
 
Other
    
726
   
755
 
Total Current Assets
    
2,083
   
2,317
 
 
          
Property, Plant, and Equipment
    
14,667
   
13,998
 
Investments
    
3,534
   
3,351
 
Deferred Charges and Other Assets
    
10,912
   
12,175
 
Total Assets
  
$
31,196
  
$
31,841
  
 
          
Liabilities and Capitalization
          
Current Liabilities:
          
Currently payable long-term debt
  
$
1,867
  
$
2,043
  
Short-term borrowings
    
1,108
   
731
 
Accounts payable
    
726 
    
727
 
Other
    
1,554 
    
1,952
 
Total Current Liabilities
    
5,255 
    
5,453
 
 
          
Capitalization:
          
Common stockholders' equity
    
8,977 
    
9,188 
  
Preferred stock
    
- 
    
184
 
Long-term debt and other long-term obligations
    
8,535
   
8,155
 
Total Capitalization
    
17,512
   
17,527
 
Noncurrent Liabilities
    
8,429
   
8,861
 
Total Liabilities and Capitalization
  
$
31,196
  
$
31,841
  
 
 

Adjusted Capitalization (Including Off-Balance Sheet Items) - Rating Agency View
  
 
  
As of December 31,
  
 
  
2006
  
% Total
  
2005
  
% Total
  
Total common equity
  
$
8.977
    
42
%
$
9,188
    
43
%
Preferred stock
   
- 
    
0
%
  
184
   
1
%
Long-term debt*
    
9,973
   
47
%
  
9,934
    
47
%
Short-term debt
    
1,108
   
5
%
  
731 
    
3
%
Off-balance sheet debt equivalents:
                  
Sale-leaseback net debt equivalents
    
1,231
   
6
%
  
1,295
   
6
%
Total
 
$
21,289
    
100
%
$
21,332
    
100
%
 
 

GENERAL INFORMATION
  
Three Months Ended Dec. 31,
 
Twelve Months Ended Dec. 31,
 
 
  
2006
  
2005
  
2006
  
2005
  
 
 
  
 
  
 
  
 
  
Debt and equity securities redemptions  
$
(1,629)
 
$
(572)
 
$
(3,329)
 
$
(1,594)
 
New long-term debt issues
  
$
1,504
  
$
387
  
$
2,739
  
$
721
  
Short-term debt increase (decrease)
  
$
(96)
  
$
484
 
$
386
  
$
561
  
Capital expenditures
  
$
325
  
$
452
  
$
1,315
  
$
1,208
  
            
             * Includes amounts due to be paid within one year and excludes JCP&L securitization debt of $429 million and $264 million in 2006 and 2005, respectively.
 
 
7
FirstEnergy Corp.
Financial Statements
(Unaudited)
(In millions, except per share amounts)
 
Condensed Consolidated Statements of Cash Flows
  
 
  
 
  
 
  
 
  
 
  
Three Months Ended Dec. 31,
  
Twelve Months Ended Dec. 31,
  
 
  
2006
  
2005
  
2006
  
2005
  
Cash flows from operating activities:
  
 
  
 
  
 
  
 
  
Net income
  
$
274
  
$
190
  
$
1,254
  
$
861
  
Adjustments to reconcile net income to net cash from operating activities:
            
Depreciation, amortization, and deferral of regulatory assets
    
227
    
342
    
957
    
1,464
  
Deferred purchased power and other costs
    
(122
)
  
(126
)
  
(445
)
  
(384
)
Deferred income taxes and investment tax credits
    
123
    
130
 
  
159 
    
154
 
Deferred rents and lease market valuation liability
    
(59
 )  
(33
)  
(113
)
  
(104
)
    Electric service prepayment programs    
(19
)
  
(10
)
  
(64
)
  
208
 
Cash collateral, net
    
21
 
  
147
    
(77
)
  
196
  
   Pension trust contribution     -      (500 )   -      (500 )
Change in working capital and other
    
251
    
164 
    
268
 
  
325
  
Cash flows provided from operating activities
    
696
    
304
    
1,939
   
2,220
  
 
                  
Cash flows provided from (used for) financing activities
    
(360
)
  
173
 
  
(804
)
  
(876
)
 
                          
Cash flows used for investing activities
    
(287
)
  
(553
)
  
(1,109
)
  
(1,333
)
Net increase (decrease) in cash and cash equivalents
  
$
49
 
$
(76
 )
$
26
 
$
11
  
 
                          
 

 
  
Three Months Ended December 31,
  
Twelve Months Ended December 31,
  
 
  
2006
  
2005
  
Change
  
2006
  
2005
  
Change
  
Ohio Regulatory Assets
                      
 
  
 
                      
 
  
Beginning balance
  
$
1,857
  
$
2,044
        
$
1,924
  
$
2,426
      
 
                                    
Deferral of shopping incentives
    
-
   
44
  
$
(44
)
  
3
   
225
  
$
(222
)
Interest on shopping incentives
    
10 
    
13
   
(3
)
  
42
   
47
    
(5
)
Deferral of MISO costs and interest
    
4
   
39
    
(35
)
  
15
    
91
    
(76
)
Deferral of RCP distribution reliability costs
    
35
    
-
   
35 
    
155
    
-
   
155
 
Deferral of RCP fuel costs
    
19
    
-
   
19 
    
113
    
-
   
113
  
Deferral of other regulatory assets
    
7
    
1
    
6
 
  
15
    
10
   
5
 
Current period deferrals
  
$
75
  
$
97
  
$
(22
)
$
343
  
$
373
  
$
(30
)
 
                                    
Ohio transition costs amortization
  
$
(59
)
$
(194
)
$
135
  
$
(270
)
$
(835
)
$
565
  
Shopping incentives amortization
    
(28
)
  
-
   
(28
)
  
(121
)
  
-
   
(121
)
MISO costs amortization
    
(5
)
  
-
   
(5
)
  
(20
)
  
-
   
(20
)
Other
     4
 
  
(23
)
  
27 
    
(12
)
  
(40
)
  
28
 
Current period amortization
  
$
(88
)
$
(217
)
$
129
  
$
(423
)
$
(875
)
$
452
  
 
                                    
Ending Balance
 
$
1,844
  
$
1,924
        
$
1,844
  
$
1,924
      
 
                                    
Deferred PJM Costs - Pennsylvania
                                    
Beginning balance
  
$
111
  
$
-
        
$
-
  
$
-
      
Deferral of PJM transmission costs
    
46 
    
-
 
$
46
    
157
   
-
 
$
157
  
Ending Balance
  
$
157
  
$
-
        
$
157
  
$
-
      
 
                                    
Deferred Energy Costs - New Jersey
                                    
Beginning balance
  
$
340
  
$
508
        
$
541
  
$
446
      
Deferral (recovery) of energy costs
    
29
 
  
33
 
$
(4
)
  
(172
)
  
95 
  
$
(267
)
Ending Balance
  
$
369
  
$
541
        
$
369
  
$
541
      
 
 
UNUSUAL ITEMS
  
Three Months Ended December 31,
  
Twelve Months Ended December 31,
  
 
  
2006
  
2005
  
Change
  
2006
  
2005
  
Change
  
 
  
 
  
 
  
 
  
 
  
 
  
 
  
Gain Non-Core Asset Sales of:
 
 
  
 
  
 
  
 
  
 
  
 
  
Amounts included in discontinued operations (a)(b)
  
$
-
  
$
-
  
$
-
  
$
-
  
$
7
  
$
(7
)
All Other, net (c)(d)
    
11
    
-
   
11
    
12
   
9
   
3
 
Total Gain on Non-Core Asset Sales
    
11
    
-
   
11
    
12
   
16
   
(4
)
Trust securities impairment (c)     (13 )   -      (13 )   (13 )    -      (13 ) 
Marbel property tax liability adjustment (l)     3     -      3      3     -      3   
PPUC NUG cost reserve for prior year (e)
    
-
 
  
-
   
-
 
  
(10
)
  
-
   
(10
)
FE Facilities sales/impairment (f)(g)
    
-
 
  
(2
 )    2
 
  
(13
)
  
(2
 )  
(11
)
MYR goodwill impairment (h)(i)     -     (9 )    9      -      (9 )   9   
Other non-core asset impairments (c)     -     (4 )    4     -     (4 )    4  
EPA settlement (c)
    
-
   
-
   
-
   
-
   
(19
)
  
19
 
Davis-Besse DOJ penalty and NRC fine (c)(i)    
-
   
(28
 )   
28
    
-
   
(31
)
  
31
 
JCP&L Rate Settlement (j)
    
-
   
-
   
-
   
-
   
28
   
(28
)
JCP&L Arbitration Decision (c)
    
-
   
-
 
  
-
    
-
   
(16
)
  
16
 
Total-Pretax Items
    
1
 
  
(43
)
  
44
    
(21
)
  
(37
 )   
16
 
 
                          
Ohio Tax Write-off and New Jersey audit adjustment (k)
    
-
   
7 
    
(7
 )   
-
   
(63
)
  
63 
  
 
                          
EPS Effect
  
$
0.01
 
$
(0.10
)
$
0.11
  
$
(0.04
)
$
(0.29
)
$
0.25
  
 
(a) Primarily FE Facilities subs and retail gas operations
  
(e) Included in "Purchased power expenses"
 
(i) Non-tax deductible
 
(b) Before income tax benefit of $12.2 million
 
(f) Included in "FE Facilities expenses"
(j) Included in "Deferral of New Regulatory Assets"
(c) Included in "Investment income"
 
(g) Before 3rd qtr 2006 tax benefit of $1.6 million
(k) Included in "Income taxes"  
 
(d) Before 2006 tax benefits (1Qtr-$2.5 M and 4Qtr-$1.6 M)  
(h) Included in "Discontinued operations"
(l) Included in "General taxes" 
  
 
 
8
FirstEnergy Corp.
Statistical Summary
(Unaudited)
 
ELECTRIC SALES STATISTICS
  
Three Months Ended December 31,
  
Nine Months Ended December 31,
  
(in millions of kWhs)
  
2006
  
2005
  
Change
  
2006
  
2005
  
Change
  
 
  
 
  
 
  
 
  
 
  
 
  
 
  
Electric Generation Sales
                          
Retail - Regulated
    
23,247
    
21,679
   
7.2
%
  
96,125
    
86,856
    
10.7
%
Retail - Competitive
    
2,833
    
3,204
    
-11.6
%
  
11,734
    
14,192
   
-17.3
%
Total Retail
    
26,080
    
24,883
    
4.8
%
  
107,859
    
101,048
    
6.7
%
Wholesale
    
5,804
   
7,036
   
-17.5
%
  
23,083 
    
28,521 
    
-19.1
%
Total Electric Generation Sales
    
31,884
   
31,919 
    
-0.1
%
  
130,942
    
129,569
    
1.1
%
 
                          
Electric Distribution Deliveries
                          
Ohio               - Residential
    
4,095
   
4,237
   
-3.4
%
  
16,762
   
17,479
   
-4.1
%
        - Commercial
    
3,521
   
3,651
    
-3.6
%
  
14,667
    
15,127
    
-3.0
%
        - Industrial
    
5,651
    
5,794
    
-2.5
%
  
23,323
    
23,544
   
-0.9
%
        - Other
    
93 
    
94
   
-1.1
%
  
374
    
383
    
-2.3
%
        Total Ohio
    
13,360 
    
13,776
    
-3.0
%
  
55,126 
    
56,533
    
-2.5
%
 
                          
Pennsylvania       -  Residential
    
2,834
   
2,864 
    
-1.0
%
  
11,278 
    
11,520
    
-2.1
%
        - Commercial
    
2,643
    
2,631
   
0.5
%
  
10,825
    
10,867
    
-0.4
%
        - Industrial
    
2,537
    
2,559
    
-0.9
%
  
10,382
    
10,441
    
-0.6
%
        - Other
    
21
   
21
   
0.0
%
  
82
   
83
    
-1.2
%
        Total Pennsylvania
    
8,035
   
8,075
   
-0.5
%
  
32,568
    
32,911
    
-1.0
%
 
                          
New Jersey          -  Residential
    
2,101
    
2,225
    
-5.6
%
  
9,548
    
10,107
    
-5.5
%
        - Commercial
    
2,247
   
2,236
   
0.5
%
  
9,450
    
9,432
    
0.2
%
        - Industrial
    
689
    
758
    
-9.1
%
  
2,831
   
3,074 
    
-7.9
%
        - Other
    
21
    
21
   
2.1
%
  
86 
    
87 
    
-0.9
%
        Total New Jersey
    
5,058 
    
5,240
   
-3.5
%
  
21,915
    
22,700
    
-3.5
%
 
                          
Total Residential
    
9,030
    
9,326
    
-3.2
%
  
37,587
    
39,106
    
-3.9
%
Total Commercial
    
8,411
    
8,518
    
-1.3
%
  
34,943
    
35,426
    
-1.4
%
Total Industrial
    
8,877
    
9,112
    
-2.6
%
  
36,537
    
37,060
    
-1.4
%
Total Other
    
136
   
136
    
-0.0
%
  
542
    
553
    
-2.0
%
Total Distribution Deliveries
    
26,454 
    
27,092
    
-2.4
%
  
109,609
    
112,145
    
-2.3
%
 
                          
Electric Sales Shopped
                          
Ohio                       - Residential
    
519 
    
1,482
    
-65.0
%
  
2,289
    
7,457
    
-69.3
%
        - Commercial
    
878 
     1,595    
-45.0
%
  
3,787
   
7,228 
    
-47.6
%
        - Industrial
    
673 
    
1,149
   
-41.4
%
  
2,874
   
4,865
    
-40.9
%
        Total Ohio
    
2,070
   
4,226
    
-51.0
%
  
8,950
    
19,550
    
-54.2
%
 
                          
Pennsylvania       - Residential
    
- 
    
5
    
-100.0
%
  
- 
    
21
    
-100.0
%
        - Commercial
    
2
    
7
    
-71.4
%
  
4
    
72
    
-94.4
%
        - Industrial
    
132
    
175
    
-24.6
%
  
501
    
1,338
   
-62.6
%
        Total Pennsylvania
    
134
    
187
    
-28.3
%
  
505
    
1,431
    
-64.7
%
 
                          
New Jersey           - Residential
    
-
   
1
   
-100.0
%
  
-
   
4 
    
-100.0
%
        - Commercial
    
478
    
427
    
11.9
%
  
1,926
    
1,985
   
-3.0
%
        - Industrial
    
525
    
572
    
-8.2
%
  
2,103
    
2,319
    
-9.3
%
        Total New Jersey
    
1,003
   
1,000
   
0.3
%
  
4,029 
    
4,308
   
-6.5
%
 
                          
Total Electric Sales Shopped
    
3,207
   
5,413 
    
-40.8
%
  
13,484
    
25,289
    
-46.7
%

 
Operating Statistics
  
Three Months Ended December 31,
  
 
  
Twelve Months Ended December 31,
  
 
  
 
  
2006
  
2005
  
 
  
2006
  
2005
  
 
  
Capacity Factors:
                           
Fossil - Baseload
    
83
%
  
78
%
        
89
%
  
87
%
      
Fossil - Load Following
    
69
%
  
70
%
        
69
%
  
67
%
      
Peaking
    
0
%
  
2
%
        
1
%
  
3
%
      
Nuclear
    
85
%
  
100
%
        
87
%
  
87
%
      
Generation Output:
                                      
Fossil - Baseload
    
41
%
  
37
%
        
42
%
  
41
%
      
Fossil - Load Following
    
23
%
  
22
%
        
22
%
  
22
%
      
Peaking
    
0
%
  
0
%
        
0
%
  
1
%
      
Nuclear
    
36
%
  
41
%
        
36
%
  
36
%
      
 
                                      
 
  
Three Months Ended December 31, 
Twelve Months Ended December 31,
WEATHER
    
2006
 
 
2005
 
 
Normal
 
 
2006
 
 
2005
 
 
Normal
  
Composite Heating-Degree-Days
    
1,715
    
2,017
    
1,974
    
4,900
    
5,703
    
5,545
  
Composite Cooling-Degree-Days
    
5
    
22
    
12
    
892
    
1,140
    
920
  
 

 
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FirstEnergy Corp.
2006 EPS and Cash Flow
(Unaudited)
 
2006 Earnings Per Share (EPS)
  
(Reconciliation of GAAP to Non-GAAP)
  
 
  
Three Months
 
Twelve Months
 
 
  
 
  
Ended Dec. 31
  
Ended Dec.31
    
 
  
 
  
 
  
 
  
Basic EPS (GAAP basis)
  
 
$0.85
  
 
$3.84
  
 
 
  
Excluding Unusual Items:
                
     Non-Core Asset Sales/Impairments
    
(0.03
)
  
-
    
 
  
     Trust securities impairment     0.02     0.02        
     PPUC NUG cost reserve for prior year
   
- 
    
0.02
    
 
  
Basic EPS (Non-GAAP basis)
  
 
$0.84
  
 
$3.88
  
 
 
  

 

 
 
Reconciliation of 2006 Cash From Operating Activities (GAAP) to
Free Cash Flow (Non-GAAP) and Cash Generation (Non-GAAP)
(In millions)
       
Net Cash from Operating Activities:
  
 
  
 
  
 
  
 Net Income
  
$
1,254
  
   Adjustments:
    
 
  
                        Depreciation
    
596
  
        Amortization of regulatory assets
    
861
  
        Deferral of new regulatory assets
    
(500
)
        Deferred purchased power costs
    
(445
)
        Deferred income taxes and ITC, net
    
159
  
        Deferred rents and lease market valuation liability
    
(113
)
        BGS collateral
    
60
 
                  Other collateral     (137 ) 
        Other, including changes in working capital
    
204
 
   Net Cash from Operating Activities (GAAP)
  
$
1,939
  
 
    
 
  
Other Items:
    
 
  
 Capital expenditures
    
(1,153
)
 Nuclear fuel fabrication
    
(162
)
 Common stock dividends
    
(586
)
 Other, net
    
12
  
Free Cash Flow (Non-GAAP)
  
$
50
 
 
        
 Proceeds from asset sales 
    
139
  
 JCP&L securitization
    
180
 
Cash Generation (Non-GAAP)*
  
$
369
  
 
*2006 cash generation was $506 million, excluding non-BGS collateral outflow of $137 million that was not included in
    2006 cash guidance.
 
 

10
 


 
 FirstEnergy Corp.
2007 EPS Guidance
(Unaudited)
 
Non-GAAP 2007 Basic Earnings Per Share Guidance
(Reconciliation of GAAP to Non-GAAP)
     
 2007 EPS
    
       Basic EPS (GAAP basis)  
 $4.10-$4.30
    
   Excluding Unusual Item:        
     Benefit from New Regulatory Asset        
          Authorized by PPUC  
(0.05)
    
   Basic EPS (Non-GAAP basis)  
 $4.05-$4.25
    
 
 
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RECENT DEVELOPMENTS

Share Repurchase Program
On January 30, 2007, FirstEnergy's Board of Directors authorized a new share repurchase program for up to 16 million shares, or 5% of outstanding common stock. At management’s discretion, shares may be acquired on the open market or through privately negotiated transactions, subject to market conditions and other factors. The Board’s authorization of the repurchase program does not require the company to purchase any additional shares and the program may be terminated at any time. The new program supersedes the prior repurchase program approved in June 2006. When combined with the approximately 10.6 million shares repurchased in August 2006 under the prior program, this new program provides FirstEnergy the opportunity to repurchase approximately 8% of its total shares outstanding as of July 2006.

Common Stock Dividend Increase
On December 19, 2006, FirstEnergy’s Board of Directors declared a quarterly dividend of $0.50 per share on outstanding common stock, an 11% increase, to be payable March 1, 2007. The new indicated annual dividend will be $2.00 per share. This action brings FirstEnergy’s total dividend increase over the past 2 years to 33%, and is consistent with our policy, which targets sustainable annual dividend growth and a payout that is appropriate for our level of earnings.
 
Record Generation Output
FirstEnergy set a new annual generation output record of 82.0 million megawatt-hours, which represented a 2.2% increase over the prior record established in 2005. The increase in generation output was primarily driven by the performance of FirstEnergy’s fossil units, which set a new annual output record of 53.0 million megawatt-hours.

Power Uprates
Beaver Valley Unit 2 and Bruce Mansfield Unit 2 experienced power uprates of 10 MW and 50 MW, respectively, during the fourth quarter of 2006 after returning to service following outages for refueling or other maintenance. These uprates were achieved in support of FirstEnergy’s operating strategy to maximize the full potential of its existing generation assets. This brings the total amount of generating capacity added through power uprates during 2006 to 99 MW.

Voluntary Pension Plan Contribution
On January 2, 2007, following the enactment of the Pension Protection Act of 2006, FirstEnergy made a voluntary $300 million contribution to its pension plan. The net after-tax cash outlay was approximately $193 million. This funding is expected to be accretive to annual earnings by approximately $0.05 per share beginning in 2007, and increases the plan’s Projected Benefit Obligation funded status to approximately 105%. Since 2004, the company has made voluntary contributions totaling $1.3 billion.

Transfer of Pollution Control Revenue Bonds
In December 2006, FirstEnergy transferred approximately $878 million of pollution control revenue bonds (PCRB) from Ohio Edison (OE), The Cleveland Electric Illuminating Company (CEI), The Toledo Edison Company (TE), and Pennsylvania Power Company (PP) to FirstEnergy Generation Corp. and FirstEnergy Nuclear Generation Corp. This transaction brings the total amount of debt transferred from the utilities to the generating companies to approximately $1.4 billion, with approximately $700 million remaining to be transferred. These PCRB transfers support the intra-system generation asset transfer that was completed in 2005, where the fossil and nuclear generating assets, excluding those that are subject to sale and leaseback arrangements with non-affiliates, were transferred from the utilities to the generation companies.

FirstEnergy Corp. Senior Note Redemption
On November 15, 2006, FirstEnergy paid at maturity the remaining $600 million of its $1.0 billion, 5.5% Senior Notes, Series A. This retirement was primarily funded with short-term debt and the proceeds of share repurchases by subsidiaries TE and CEI enabled by their new Senior Note issuances. The initial $400 million of principal was redeemed via a make-whole call provision in July 2006.


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Rating Agency Update
On February 2, 2007, Fitch Ratings upgraded the Issuer Default Rating of FirstEnergy and its subsidiaries Jersey Central Power & Light (JCP&L), CEI, and TE. At the same time, Fitch affirmed the ratings of OE and its subsidiary PP. The rating outlook is positive for CEI and TE, and stable for FirstEnergy and the other rated subsidiaries. Fitch indicated that the rating changes reflect the improved operating performance of the generating fleet, balance sheet de-leveraging, and relatively constructive regulatory environments.

Sale and Leaseback of Bruce Mansfield Unit 1
On January 31, 2007, FirstEnergy announced its intention to pursue a sale and leaseback transaction for its owned 776 MW portion of Bruce Mansfield Unit 1. If consummated as currently contemplated, FirstEnergy expects the after-tax proceeds of this transaction to be approximately $1.2 billion, which are anticipated to be used to fund the recently authorized share repurchase program and the repayment of short-term debt, including amounts incurred in connection with the recent pension contribution. The Company is currently targeting a close in the second quarter of 2007.

JCP&L Non-Utility Generation Clause (NGC) Settlement
On December 6, 2006, the New Jersey Board of Public Utilities approved a stipulation of settlement in an NGC rate proceeding allowing JCP&L to recover $165 million of deferred costs over an 18-month period. The costs were incurred by JCP&L during the period August 1, 2003, through December 31, 2005 to meet a portion of customers’ generation needs with mandated non-utility generation (NUG) supply contracts. The approved stipulation increases JCP&L’s cash flow, but is earnings neutral.

Met-Ed and Penelec Rate Transition Plan Update
On January 11, 2007, the PPUC issued its order in the Metropolitan Edison (Met-Ed) and Pennsylvania Electric Company (Penelec) Rate Transition Plan cases, approving overall rate increases for Met-Ed of 5% ($59 million) and Penelec of 4.5% ($50 million). As a result of the failure to obtain adequate rate relief, Met-Ed recorded a goodwill impairment charge of $358 million in the fourth quarter of 2006. The goodwill at Met-Ed resulted from the November 2001 merger between FirstEnergy and GPU, Inc., Met-Ed's former parent company. No adjustment to the consolidated goodwill of Met-Ed's parent, FirstEnergy, will be made since the fair value of its regulated segment (which represents FirstEnergy's reporting unit to evaluate goodwill) continues to exceed the carrying value of its investment in the segment.

Several parties to the proceeding, including Met-Ed and Penelec, filed Petitions for Reconsideration of the Order with the Pennsylvania Public Utility Commission (PPUC). Parties have until 30 days after the PPUC rules on the Petitions to file appeals with the Commonwealth Court.

2007 Non-GAAP Earnings Guidance
On January 31, 2007, FirstEnergy issued 2007 non-GAAP earnings guidance of $4.05 to $4.25 per share. On a GAAP basis, 2007 earnings are expected to be $4.10 to $4.30 per share, which includes a $0.05 per share benefit for new regulatory assets authorized by the PPUC in January 2007 that apply to prior years.



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Forward-looking Statements.  This Consolidated Report to the Financial Community includes forward-looking statements based on information currently available to management. Such statements are subject to certain risks and uncertainties. These statements typically contain, but are not limited to, the terms “anticipate,” “potential,” “expect,” “believe,” “estimate” and similar words. Actual results may differ materially due to the speed and nature of increased competition and deregulation in the electric utility industry, economic or weather conditions affecting future sales and margins, changes in markets for energy services, changing energy and commodity market prices, replacement power costs being higher than anticipated or inadequately hedged, the continued ability of our regulated utilities to collect transition and other charges or to recover increased transmission costs, maintenance costs being higher than anticipated, legislative and regulatory changes (including revised environmental requirements), and the legal and regulatory changes resulting from the implementation of the Energy Policy Act of 2005 (including, but not limited to, the repeal of the Public Utility Holding Company Act of 1935), 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 New Source Review litigation, adverse regulatory or legal decisions and outcomes (including, but not limited to, the revocation of necessary licenses or operating permits, fines or other enforcement actions and remedies) of governmental investigations and oversight, including by the Securities and Exchange Commission, the Nuclear Regulatory Commission and the various state public utility commissions as disclosed in our Securities and Exchange Commission filings, generally, and heightened scrutiny at the Perry Nuclear Power Plant in particular, the timing and outcome of various proceedings before the Public Utilities Commission of Ohio (PUCO) (including, but not limited to, the successful resolution of the issues remanded to the PUCO by the Ohio Supreme Court regarding the Rate Stabilization Plan) and the PPUC, including the transition rate plan filings for Met-Ed and Penelec, the continuing availability and operation of generating units, the ability of generating units to continue to operate at, or near full capacity, the inability to accomplish or realize anticipated benefits from strategic goals (including employee workforce initiatives), the anticipated benefits from voluntary pension plan contributions, the ability to improve electric commodity margins and to experience growth in the distribution business, the ability to access the public securities and other capital markets and the cost of such capital, the outcome, cost and other effects of present and potential legal and administrative proceedings and claims related to the August 14, 2003 regional power outage, the successful structuring and completion of a potential sale and leaseback transaction for Bruce Mansfield Unit 1 currently under consideration by management, the successful implementation of the newly-approved share repurchase program announced on January 31, 2007, the risks and other factors discussed from time to time in our Securities and Exchange Commission filings, including our annual report on Form 10-K for the year ended December 31, 2005, and other similar factors. Dividends declared from time to time during any annual period may in aggregate vary from the indicated amounts due to circumstances considered by the Board at the time of the actual declarations. We expressly disclaim any current intention to update any forward-looking statements contained herein as a result of new information, future events, or otherwise.

14