Exhibit 99.1

    

FOR IMMEDIATE RELEASE

Contact: Chaka Patterson

Investor Relations

312-394-7234

Jennifer Medley

Corporate Communications

312-394-7189

Exelon Announces Strong Fourth Quarter and Full Year 2007 Results;

Nuclear Operations Set New Records

CHICAGO (January 23, 2008) – Exelon Corporation’s (Exelon) fourth quarter 2007 consolidated earnings prepared in accordance with GAAP were $562 million, or $0.84 per diluted share, compared with earnings of $592 million, or $0.87 per share, in the fourth quarter of 2006. Full year 2007 consolidated earnings prepared in accordance with GAAP were $2,736 million, or $4.05 per diluted share, compared with $1,592 million, or $2.35 per diluted share in 2006.

“Our company and its employees delivered an exceptional year in 2007. Our results reflected both improved generation margins and excellent operating performance, including all-time record-setting nuclear output and fleet capacity factors. In addition, our nuclear fleet recorded its lowest industrial safety accident rate ever,” said John W. Rowe, Exelon’s chairman, president and CEO. “ComEd and PECO also had strong performance amid severe storms and hot weather late last summer. We are now at work to meet, and if possible to exceed, the financial and operating targets we have set for 2008.”

Full Year Operating Results

Full year 2007 adjusted (non-GAAP) operating earnings were $2,923 million, or $4.32 per diluted share, up 34 percent over 2006 adjusted (non-GAAP) operating earnings of $2,175 million, or $3.22 per diluted share. The full year adjusted (non-GAAP) operating earnings improvement was due to higher margins on energy sales at Exelon Generation Company, LLC (Generation), authorized transmission and delivery service revenue increases for Commonwealth Edison Company (ComEd), and higher electric delivery volume at ComEd and PECO Energy Company (PECO). These positive factors were partially offset by significantly lower net income at ComEd primarily due to the end of its nearly ten-year regulatory transition period, higher operating and maintenance expense, and increased depreciation and amortization primarily related to the scheduled higher competitive transition charge (CTC) amortization at PECO.

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Fourth Quarter Operating Results

Exelon’s adjusted (non-GAAP) operating earnings for the fourth quarter of 2007 were $677 million, or $1.02 per diluted share, compared with $487 million, or $0.72 per diluted share, for the same period in 2006. The increase in adjusted (non-GAAP) operating earnings per share was primarily due to the higher margins at Generation, the transmission and delivery service revenue increases for ComEd, and the effects of favorable weather conditions as compared with the prior year in the ComEd and PECO service territories. These positive factors were partially offset by the impacts of the end of the Illinois transition period at ComEd, higher operating and maintenance expense, and increased depreciation and amortization expense.

Adjusted (non-GAAP) operating earnings for the fourth quarter of 2007 do not include the following items, representing an after-tax net loss of $115 million, or $0.18 per diluted share, that are included in reported GAAP earnings (all after tax):

• A charge of $184 million, or $0.28 per diluted share, for the costs associated with the Illinois electric rate settlement agreement, including ComEd’s customer rate relief programs announced in April 2007.

• Income of $130 million, or $0.19 per diluted share, for termination of the State Line Energy, L.L.C. power purchase agreement (PPA).

• A charge of $72 million, or $0.11 per diluted share, associated with Generation’s tolling agreement with Georgia Power related to the contract with Tenaska Georgia Partners, LP.

• Income of $29 million, or $0.04 per diluted share, related to non-cash deferred tax items.

• Earnings of $18 million, or $0.03 per diluted share, associated with investments in synthetic fuel-producing facilities, including the impact of mark-to-market losses associated with the related derivatives.

• Mark-to-market losses of $22 million, or $0.03 per diluted share, primarily from Generation’s economic hedging activities.

• A charge of $14 million, or $0.02 per diluted share, associated with ComEd’s settlement agreement with the City of Chicago.

Adjusted (non-GAAP) operating earnings for the fourth quarter of 2006 did not include the following items, representing an after-tax net gain of $105 million, or $0.15 per diluted share, that were included in reported GAAP earnings (all after tax):

• A one-time benefit of $95 million, or $0.14 per diluted share, to recover previously incurred severance costs related to ComEd’s December 20, 2006 amended Illinois Commerce Commission (ICC) order.

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• Earnings of $31 million, or $0.04 per diluted share, associated with investments in synthetic fuel-producing facilities, including the impact of mark-to-market losses associated with the related derivatives.

• Mark-to-market losses of $17 million, or $0.03 per diluted share, primarily from Generation’s economic hedging activities.

2008 Earnings Outlook

Exelon affirmed its adjusted (non-GAAP) operating earnings guidance range for 2008 of $4.00 to $4.40 per share. The following table indicates estimated contribution ranges by operating company to 2008 adjusted (non-GAAP) operating earnings per Exelon share, excluding Exelon holding company.

Generation:	$3.15 to $3.45
ComEd:	$0.35 to $0.40
PECO:	$0.55 to $0.60

The outlook for 2008 adjusted (non-GAAP) operating earnings for Exelon and its subsidiaries excludes the following items:

• mark-to-market adjustments from economic hedging activities

• unrealized gains and losses from nuclear decommissioning trust fund investments

• significant impairments of assets, including goodwill

• significant changes in decommissioning obligation estimates

• costs associated with the Illinois electric rate settlement agreement, including ComEd’s previously announced customer rate relief programs

• costs associated with ComEd’s settlement with the City of Chicago

• other unusual items

• significant future changes to GAAP

Giving consideration to these factors, Exelon estimates GAAP earnings in 2008 will fall in the range of $3.70 to $4.10 per share. Both Exelon’s operating earnings and GAAP earnings guidance are based on the assumption of normal weather.

Fourth Quarter and Recent Highlights

• Value Return (Dividend Increase and Share Repurchase): On December 19, 2007, Exelon announced that its board of directors had declared a regular first-quarter 2008 common stock dividend of $0.50 per share, a 14 percent increase over the dividend for the fourth quarter of 2007. The first-quarter dividend is payable on March 10, 2008, to Exelon shareholders of record at 5:00 p.m. New York Time on February 15, 2008. In December 2006, Exelon’s board of directors approved a value return policy that established an annual base dividend rate of $1.76 per share, which was expected to grow modestly over time. Largely due to improved power market fundamentals and Exelon’s superior operations, the board of directors reset the annual

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base dividend rate at $2.00 per share. Exelon expects to grow the dividend modestly over time. Future dividends are subject to declaration by the board of directors.

Also on December 19, 2007, Exelon’s board of directors authorized a new share repurchase program of up to $500 million of Exelon’s outstanding common stock. This new program is in addition to the $1.25 billion share repurchase executed in September 2007 and to any additional share repurchases that may be authorized by the board of directors later in 2008 based on availability of cash and other factors. Exelon’s value return policy considers the use of share repurchases from time to time, when authorized by the board of directors, to return cash or balance sheet capacity to Exelon shareholders after funding maintenance capital and other commitments and in the absence of higher value-added growth opportunities.

• Nuclear Operations: Generation’s nuclear fleet, including its owned output from the Salem Generating Station operated by PSEG Nuclear LLC, produced 34,296 GWhs in the fourth quarter of 2007, compared with 34,810 GWhs in the fourth quarter of 2006. The Exelon-operated nuclear plants completed four scheduled refueling outages in the fourth quarter of 2007 (91 days), compared with completing five refueling outages in the fourth quarter of 2006 (88 days). Nuclear output was also negatively impacted by a higher number of non-refueling outage days, 27 days in the fourth quarter of 2007 versus 18 days in 2006.

For the full year 2007, the Exelon-operated nuclear plants achieved an average capacity factor of 94.5 percent, an all-time record for the company, compared with 93.9 percent for 2006. The Exelon-operated plants have achieved average capacity factors of more than 93 percent in each of the past five years. In addition, the Exelon-operated nuclear plants produced a total of 132,341 GWhs in 2007, their highest annual production ever.

• Fossil and Hydro Operations: Generation’s fossil fleet commercial availability was 83.0 percent in the fourth quarter of 2007, compared with 95.7 percent in the fourth quarter of 2006, primarily due to outages at two units during the fourth quarter of 2007. The equivalent availability factor for the hydro facilities was 98.6 percent in the fourth quarter of 2007, compared with 97.9 percent in the fourth quarter of 2006. Despite the higher hydro fleet equivalent availability factor in 2007, lower river flow actually resulted in lower generation during 2007 compared to 2006.

• Zion Station Decommissioning: On December 11, 2007, Exelon Nuclear announced that it will seek to accelerate the decommissioning of its Zion Station in Illinois more than a decade earlier than originally planned. The company has contracted with EnergySolutions, Inc. to dismantle the nuclear plant, which closed in 1998. Completion of the arrangement is subject to the satisfaction of a number of closing conditions, including the receipt of a private letter ruling from the Internal Revenue Service. Additionally, the Nuclear Regulatory Commission (NRC) must approve the arrangement, and this decision is not expected before the second half of 2008. Upon approval, the Zion Station’s licenses and decommissioning funds would be transferred to EnergySolutions, Inc.

• Nuclear Site Designation: On December 18, 2007, Exelon Nuclear announced that it had selected Victoria County, Texas as its site for a federal license application that would allow construction and operation of a new nuclear plant should the company decide to build one. Exelon Nuclear expects to submit the combined Construction & Operating License (COL)

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application to the NRC in late 2008. Exelon Nuclear will use GE Hitachi Nuclear Energy Americas’ new generation of reactor technology – Economic Simplified Boiling Water Reactor, or ESBWR – if it decides to build a new nuclear plant.

• Nuclear Plant Licenses: On January 8, 2008, AmerGen Energy Company, LLC, a subsidiary of Generation, submitted an application to the NRC to extend the operating license of Three Mile Island Unit 1 (TMI) Generating Station by 20 years. TMI, an 852-MW unit in Dauphin County, Pennsylvania, began commercial operations in 1974. Its current operating license expires in April 2014. NRC approval of the application would extend the license until April 2034. The NRC is expected to spend 22 to 30 months to review the application before making a decision.

The NRC is also currently reviewing a license renewal application for Oyster Creek Generating Station in New Jersey filed in July 2005. In December 2007 and January 2008, two milestones in this license renewal process were achieved – the NRC Atomic Safety and Licensing Board decision regarding the safety of the drywell containment structure and the New Jersey Department of Environmental Protection certification regarding compliance with the Federal Coastal Zone Management Act. As a result, Generation expects to receive approval from the NRC during 2008.

• Settlement Agreement with the City of Chicago: On December 21, 2007, ComEd entered into a settlement agreement with the City of Chicago (City). The settlement agreement is a comprehensive agreement addressing a wide range of issues and disputes between ComEd and the City. The City has agreed not to challenge ComEd’s position in rate case proceedings under certain conditions during the term of the settlement agreement. In addition, ComEd will support the City’s energy efficiency programs and will be able to reprioritize or eliminate several projects. The principal terms of the settlement agreement require ComEd to pay the City a total of $55 million through 2012 as long as the City meets specified conditions. The schedule of payments is $23 million in 2007, which was paid in December, $18 million in 2008, $8 million in 2009, $3 million in 2010, $1 million in 2011 and $2 million in 2012.

• ComEd Distribution Rate Case: On October 17, 2007, ComEd filed a request with the ICC seeking approval to increase its delivery service revenue requirement by approximately $360 million to reflect ComEd’s continued substantial investment in its delivery system. The rate case filing is based on a 2006 test year. If approved by the ICC, the total increase would raise the average ComEd residential customer total bill about 7.7 percent. ICC proceedings will take place over a period of up to eleven months.

• ComEd Transmission Rate Case: On March 1, 2007, ComEd filed a request with the Federal Energy Regulatory Commission (FERC), seeking approval to increase its annual revenue requirement for transmission services by $146 million and to implement a formula-based transmission rate. ComEd’s filing also included a request for incentive rate treatment for two major new transmission projects. On June 5, 2007, FERC conditionally allowed ComEd to implement its formula-based transmission rate and associated rate adjustment, effective May 1, 2007 subject to refund, and provided for further hearing and settlement discussions. The new conditionally approved rate increased the annual revenue requirement by $116 million and raised the average residential customer bill by approximately 1 percent. On June 5, 2007, FERC denied the request for incentive rate treatment for the new transmission projects, and ComEd filed a request for rehearing regarding the incentives on July 5, 2007.

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On October 5, 2007, ComEd made a filing with FERC seeking approval of a settlement agreement reached among ComEd, the FERC Trial Staff and the active interveners in the proceeding. The settlement agreement provides for an initial increase in the revenue requirement of $93 million (effective as of May 1, 2007), or a $23 million reduction from the revenue requirement conditionally approved by FERC in its June 2007 order. The settlement agreement is a comprehensive resolution of all issues in the proceeding, other than ComEd’s request for rehearing at FERC on the incentive returns. FERC approved the settlement agreement on January 16, 2008. ComEd believes that appropriate reserves have been established for this issue.

On January 18, 2008, FERC issued an order on rehearing approving, in part, incentive rate treatment. The January 18, 2008 order approved the inclusion of construction work in progress (CWIP) in rate base for ComEd’s investment in a new 345-kV transmission line in Chicago’s West Loop and allowed a 1.50 percent adder to the return on equity on the project, but denied incentive rate treatment on a smaller transmission project. The inclusion of CWIP in rate base and the return on equity adder for the West Loop project will increase the revenue requirement, effective May 1, 2007.

• ComEd Procurement Filing: The August 2007 Settlement Legislation established a new competitive process that must be used in the future for procurement of electricity by Illinois utilities, replacing the reverse-auction bidding process used in 2006. The power contracts awarded as a result of the 2006 reverse-auction will remain in effect through their original terms, but as those contracts expire, the power will be replaced with contracts awarded through the new process. ComEd is responsible for implementing an initial procurement plan to replace one-third of the auction supply for the period June 2008 to May 2009. For power needs beginning June 2009, the Illinois Power Agency (IPA) will take over responsibility for the design of a procurement plan for ComEd and will administer a request for proposal (RFP) process for ComEd to procure the electricity supply products identified in the procurement plan, all with the oversight of the ICC. On December 19, 2007, the ICC approved ComEd’s request related to procurement for the initial delivery period. An independent administrator will conduct the procurement through a sealed-bid, RFP process. ComEd’s initial procurement plan will be used to provide approximately one-third of ComEd’s electricity supply from June 2008 through May 2009. However, the energy price for approximately half of the one-third of supply being procured through this plan has been hedged through the previously disclosed financial swap contract with Generation.

• ComEd Energy Efficiency Filing: On November 15, 2007, ComEd filed a proposed slate of programs with the ICC to meet energy reduction targets over a three-year period. If targets are met, ComEd customers would reduce their electricity consumption by a cumulative amount of approximately 1.2 million MWh at the end of the three years. Savings on customers’ bills is expected to pay for the cost of implementing the programs and produce additional net savings of more than $155 million over the lifetime of the programs. Once implemented, the programs would place ComEd among the top three utilities in the nation in terms of annual electricity savings achieved through energy efficiency.

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• Pennsylvania Energy Independence Plan and Legislative Update: The Pennsylvania General Assembly returned to session on January 14, 2008 to consider, among other things, elements of energy legislation previously proposed by Pennsylvania’s Governor. Legislation under consideration includes such measures as a phase-in of increased generation rates after expiration of rate caps, installation of metering technology to provide time-of-use rates to retail customers, and creation of a fee on electric consumption that would help fund an $850 million Energy Independence Fund designed to spur biofuels development and promote energy efficiency and renewable energy initiatives. The Governor’s proposed legislation also includes a requirement for default suppliers such as PECO to procure electricity for their default-service customers after the end of their electric restructuring period (post-2010 for PECO) through a least-cost portfolio approach, with preferences for conservation and renewable power, and permits distribution companies to enter into long-term procurement contracts to enable construction of new generation. PECO supports the development of a legislative package to help customers manage rising energy prices and increase the use of environmentally friendly alternative fuel sources to meet Pennsylvania’s growing energy needs.

• PECO Alternative Energy Portfolio Standards (AEPS) Filing: On December 26, 2007, the Pennsylvania Public Utility Commission (PAPUC) approved PECO’s proposal to begin to purchase alternative energy credits in fulfillment of Pennsylvania’s AEPS legislation. The AEPS legislation requires that, by 2011, 3.5 percent of the energy consumed by PECO customers must be provided through alternative resources – such as wind, methane gas and biomass. The legislation further requires a  ¹/2 percent annual increase in alternative requirements, ensuring that by 2020, alternative resources will make up a total of 8 percent of the energy consumed by PECO customers. PECO will meet the initial requirement by purchasing the equivalent of 240 MWs of alternative energy credits over each of the next five years. A credit is generated each time one MWh of alternative energy is produced. Using an independent RFP monitor, PECO will conduct an RFP process for alternative energy producers to submit bids to sell credits.

• Financing Activities: On December 31, 2007, Generation issued $46.4 million of variable-rate, tax-exempt bonds due 2042. The proceeds will be used to finance Generation’s portion of the costs to construct, install and equip emissions-control facilities at the two-unit, 1,700-MW coal-fired Keystone Generating Station located in Armstrong County, Pennsylvania.

On January 16, 2008, ComEd issued $450 million of 6.45 percent First Mortgage Bonds due 2038. ComEd used the net proceeds from the sale of the bonds to refinance trust preferred securities and will refinance maturing First Mortgage Bonds.

OPERATING COMPANY RESULTS

Exelon Generation consists of owned and contracted electric generating facilities, wholesale energy marketing operations and competitive retail sales operations.

Fourth quarter 2007 net income was $343 million compared with $245 million in the fourth quarter of 2006. Fourth quarter 2007 net income included (all after tax) a charge of $179 million for the costs associated with the Illinois electric rate settlement, income of $130 million for termination of the State Line PPA, a charge of $72 million associated with the tolling agreement with Georgia Power, charges of $34 million related to non-cash deferred tax items, and mark-to-market losses of $21 million from

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economic hedging activities. Fourth quarter 2006 net income included (all after tax) mark-to-market losses of $17 million from economic hedging activities, severance and severance-related charges of $1 million and an impairment charge of $1 million related to its investments in Termoeléctrica del Golfo (TEG) and Termoeléctrica Peñoles (TEP), the sale of which closed in February 2007. Excluding the impact of these items, Generation’s net income in the fourth quarter of 2007 increased $255 million compared with the same quarter last year, primarily due to higher revenue, net of purchased power and fuel expense, more than offsetting inflationary and other cost pressures and costs associated with the new nuclear plant COL application.

Generation’s revenue, net of purchased power and fuel expense, increased by $441 million in the fourth quarter of 2007 compared with the fourth quarter of 2006 excluding the mark-to-market impacts, costs associated with the Illinois electric rate settlement, income related to the termination of the State Line PPA and the loss associated with the tolling agreement with Georgia Power. The increase in revenue, net of purchased power and fuel expense, was driven by higher average margins primarily due to the end of the below-market price PPA with ComEd at year-end 2006 and the contractual increase in the prices associated with Generation’s PPA with PECO. Generation’s average realized margin on all electric sales, including sales to affiliates and excluding trading activity, was $35.70 per MWh in the fourth quarter of 2007 compared with $24.81 per MWh in the fourth quarter of 2006.

ComEd consists of the electricity transmission and distribution operations in northern Illinois.

ComEd recorded net income of $67 million in the fourth quarter of 2007, compared with net income of $213 million in the fourth quarter of 2006. Fourth quarter 2007 net income included (all after tax) a charge of $5 million for the costs associated with the Illinois electric rate settlement, including ComEd’s previously announced customer rate relief programs, a charge of $14 million for the City of Chicago settlement agreement and mark-to-market gains of $2 million. Fourth quarter 2006 net income included a one-time after-tax benefit of $95 million attributable to the ICC’s December 20, 2006 amended order to recover previously incurred severance costs. Excluding the impact of these items, ComEd’s net income in the fourth quarter of 2007 decreased $34 million compared with the same quarter last year, primarily due to the end of its regulatory transition period, and higher operating and maintenance expense, which partially reflected increased labor and contracting costs and allowance for uncollectible accounts expense. These items were partially offset by the FERC-approved transmission rate increase and ICC-authorized increase in delivery service rates. In addition, ComEd recorded a net benefit associated with a change in its tax method of capitalizing overhead costs.

In the ComEd service territory in the fourth quarter of 2007, heating degree-days were up 1 percent relative to the same period in 2006 but were 7 percent below normal. ComEd’s total retail kWh deliveries increased 3 percent in 2007 as compared with 2006, with a 3 percent increase in deliveries to the residential customer class, largely due to colder weather. ComEd’s fourth quarter 2007 revenues were $1,436 million, up 4 percent from $1,381 million in 2006 primarily due to the above-mentioned rate increases plus increases in the cost of power and the impact of favorable weather, partially offset by customers switching to alternative electric generation suppliers. For ComEd, weather had a favorable after-tax impact of $10 million on fourth quarter 2007 earnings relative to 2006 and a favorable after-tax impact of $5 million relative to normal weather, which was incorporated in earnings guidance.

The number of customers being served in the ComEd region increased by 1.0 percent since the fourth quarter of 2006, and weather-normalized kWh retail deliveries increased by 0.6 percent compared with the fourth quarter of 2006.

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PECO consists of the electricity transmission and distribution operations and the retail natural gas distribution business in southeastern Pennsylvania.

PECO’s net income in the fourth quarter of 2007 was $115 million, a decrease from net income of $121 million in the fourth quarter of 2006. Fourth quarter 2006 net income included after-tax severance and severance-related charges of $1 million. Excluding the impact of this item, PECO’s net income in the fourth quarter of 2007 decreased $7 million compared with the same quarter last year, primarily due to higher operating and maintenance expense, which partially reflected increased labor and contracting costs and allowance for uncollectible accounts expense, and higher CTC amortization, which was in accordance with PECO’s 1998 restructuring settlement with the PAPUC. As expected, the increase in amortization expense exceeded the increase in CTC revenues. These items were partially offset by higher revenues, net of purchased power and fuel expense, largely due to the effects of favorable weather compared to 2006. In addition, PECO recorded a net benefit associated with a change in its tax method of capitalizing overhead costs.

In the PECO service territory in the fourth quarter of 2007, heating degree-days were up 12 percent from 2006 but were 8 percent below normal. PECO’s total electric retail kWh deliveries increased 4 percent, with residential deliveries up 3 percent. Total gas retail deliveries were up 16 percent from the 2006 period. PECO’s fourth quarter 2007 revenues were $1,385 million, up from $1,235 million in 2006, primarily due to the effects of an authorized electric generation rate increase under the 1998 restructuring settlement and the effects of favorable weather compared with 2006. For PECO, weather had a favorable after-tax impact of $23 million on fourth quarter 2007 earnings relative to 2006 and a favorable after-tax impact of $5 million relative to normal weather, which was incorporated in earnings guidance. The favorable impact relative to normal weather reflected a significant increase in cooling degree-days in October due to unusually warm weather.

The number of electric customers being served in the PECO region increased by 0.8 percent since the fourth quarter of 2006, with weather-normalized kWh growth of 2.9 percent compared with the fourth quarter of 2006.

Adjusted (non-GAAP) Operating Earnings

Adjusted (non-GAAP) operating earnings, which generally exclude significant one-time charges or credits that are not normally associated with ongoing operations and mark-to-market adjustments from economic hedging activities, are provided as a supplement to results reported in accordance with GAAP. Management uses such adjusted (non-GAAP) operating earnings measures internally to evaluate the company’s performance and manage its operations. Reconciliations of GAAP to adjusted (non-GAAP) operating earnings for historical periods are attached. Additional earnings release attachments, which include the reconciliations on pages 7 and 8, are posted on Exelon’s Web site: www.exeloncorp.com and have been filed with the Securities and Exchange Commission on Form 8-K on January 23, 2008.

Conference call information: Exelon has scheduled a conference call for 11 AM ET (10 AM CT) on January 23, 2008. The call-in number in the U.S. is 800-690-3108, and the international call-in number is 973-935-8753. If requested, the conference ID number is 29883087. Media representatives are invited to participate on a listen-only basis. The call will be web-cast and archived on Exelon’s Web site: www.exeloncorp.com. (Please select the Investor Relations page.)

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Telephone replays will be available until February 6. The U.S. call-in number for replays is 800-642-1687, and the international call-in number is 706-645-9291. The conference ID number is 29883087.

This news release includes forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995, that are subject to risks and uncertainties. The factors that could cause actual results to differ materially from these forward-looking statements include those discussed herein as well as those discussed in (1) Exelon’s 2006 Annual Report on Form 10-K in (a) ITEM 1A. Risk Factors, (b) ITEM 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations and (c) ITEM 8. Financial Statements and Supplementary Data: Note 18; (2) Exelon’s Third Quarter 2007 Quarterly Report on Form 10-Q in (a) Part II, Other Information, ITEM 1A. Risk Factors and (b) Part I, Financial Information, ITEM 1. Financial Statements: Note 13; and (3) other factors discussed in filings with the Securities and Exchange Commission (SEC) by Exelon Corporation, Commonwealth Edison Company, PECO Energy Company and Exelon Generation Company, LLC (Companies). Readers are cautioned not to place undue reliance on these forward-looking statements, which apply only as of the date of this news release. None of the Companies undertakes any obligation to publicly release any revision to its forward-looking statements to reflect events or circumstances after the date of this news release.

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Exelon Corporation is one of the nation’s largest electric utilities with approximately 5.4 million customers and $19 billion in annual revenues. The company has one of the industry’s largest portfolios of electricity generation capacity, with a nationwide reach and strong positions in the Midwest and Mid-Atlantic. Exelon distributes electricity to approximately 5.4 million customers in Illinois and Pennsylvania and natural gas to more than 480,000 customers in southeastern Pennsylvania. Exelon is headquartered in Chicago and trades on the NYSE under the ticker EXC.

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EXELON CORPORATION

Earnings Release Attachments

Table of Contents

Consolidating Statements of Operations - Three Months Ended December 31, 2007 and 2006	1
Consolidating Statements of Operations - Twelve Months Ended December 31, 2007 and 2006	2
Business Segment Comparative Statements of Operations - Generation and ComEd - Three and Twelve Months Ended December 31, 2007 and 2006	3
Business Segment Comparative Statements of Operations - PECO and Other - Three and Twelve Months Ended December 31, 2007 and 2006	4
Consolidated Balance Sheets - December 31, 2007 and 2006	5
Consolidated Statements of Cash Flows - Twelve Months Ended December 31, 2007 and 2006	6
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Consolidated Statements of Operations - Exelon - Three Months Ended December 31, 2007 and 2006	7
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Consolidated Statements of Operations - Exelon - Twelve Months Ended December 31, 2007 and 2006	8
Reconciliation of Adjusted (non-GAAP) Operating Earnings Per Diluted Share to GAAP Earnings Per Diluted Share - Three Months Ended December 31, 2007 and 2006	9
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Earnings By Business Segment - Three Months Ended December 31, 2007 and 2006	10
Reconciliation of Adjusted (non-GAAP) Operating Earnings Per Diluted Share to GAAP Earnings Per Diluted Share - Twelve Months Ended December 31, 2007 and 2006	11
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Earnings By Business Segment - Twelve Months Ended December 31, 2007 and 2006	12
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Consolidated Statements of Operations - Generation - Three and Twelve Months Ended December 31, 2007 and 2006	13
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Consolidated Statements of Operations - ComEd - Three and Twelve Months Ended December 31, 2007 and 2006	14
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Consolidated Statements of Operations - PECO - Three and Twelve Months Ended December 31, 2007 and 2006	15
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Consolidated Statements of Operations - Other - Three and Twelve Months Ended December 31, 2007 and 2006	16
Exelon Generation Statistics - Three Months Ended December 31, 2007, September 30, 2007, June 30, 2007, March 31, 2007 and December 31, 2006	17
Exelon Generation Statistics - Twelve Months Ended December 31, 2007 and 2006	18
ComEd Sales Statistics - Three Months Ended December 31, 2007 and 2006	19
ComEd Sales Statistics - Twelve Months Ended December 31, 2007 and 2006	20
PECO Sales Statistics - Three Months Ended December 31, 2007 and 2006	21
PECO Sales Statistics - Twelve Months Ended December 31, 2007 and 2006	22

EXELON CORPORATION

Consolidating Statements of Operations

(unaudited)

(in millions)

	Three Months Ended December 31, 2007
	Generation			ComEd			PECO			Other			Exelon Consolidated
Operating revenues	$	2,568		$	1,436		$	1,385		$	(835	)	$	4,554
Operating expenses
Purchased power		766			841			571			(827	)		1,351
Fuel		372			—			194			(2	)		564
Operating and maintenance		654			313			185			23			1,175
Depreciation and amortization		67			114			182			11			374
Taxes other than income		49			71			68			6			194
Total operating expenses		1,908			1,339			1,200			(789	)		3,658
Operating income (loss)		660			97			185			(46	)		896
Other income and deductions
Interest expense, net		(62	)		(58	)		(60	)		(33	)		(213	)
Equity in losses of unconsolidated affiliates and investments		—			(2	)		(2	)		(13	)		(17	)
Other, net		87			48			10			91			236
Total other income and deductions		25			(12	)		(52	)		45			6
Income (loss) from continuing operations before income taxes		685			85			133			(1	)		902
Income taxes		341			18			18			(37	)		340
Income from continuing operations		344			67			115			36			562
Income (loss) from discontinued operations		(1	)		—			—			1			—
Net income	$	343		$	67		$	115		$	37		$	562
	Three Months Ended December 31, 2006
	Generation			ComEd			PECO			Other			Exelon Consolidated
Operating revenues	$	2,074		$	1,381		$	1,235		$	(994	)	$	3,696
Operating expenses
Purchased power		420			669			493			(991	)		591
Fuel		467			—			154			—			621
Operating and maintenance		623			101			149			6			879
Depreciation and amortization		70			110			162			10			352
Taxes other than income		51			69			64			6			190
Total operating expenses		1,631			949			1,022			(969	)		2,633
Operating income (loss)		443			432			213			(25	)		1,063
Other income and deductions
Interest expense, net		(39	)		(78	)		(64	)		(36	)		(217	)
Equity in losses of unconsolidated affiliates and investments		—			(2	)		(2	)		(33	)		(37	)
Other, net		11			6			14			30			61
Total other income and deductions		(28	)		(74	)		(52	)		(39	)		(193	)
Income (loss) from continuing operations before income taxes		415			358			161			(64	)		870
Income taxes		170			145			40			(78	)		277
Income from continuing operations		245			213			121			14			593
Loss from discontinued operations		—			—			—			(1	)		(1	)
Net income	$	245		$	213		$	121		$	13		$	592

1

EXELON CORPORATION

Consolidating Statements of Operations

(unaudited)

(in millions)

	Twelve Months Ended December 31, 2007
	Generation			ComEd			PECO			Other			Exelon Consolidated
Operating revenues	$	10,749		$	6,104		$	5,613		$	(3,550	)	$	18,916
Operating expenses
Purchased power		2,705			3,747			2,366			(3,536	)		5,282
Fuel		1,746			—			617			(3	)		2,360
Operating and maintenance		2,454			1,091			630			114			4,289
Depreciation and amortization		267			440			773			40			1,520
Taxes other than income		185			314			280			18			797
Total operating expenses		7,357			5,592			4,666			(3,367	)		14,248
Operating income (loss)		3,392			512			947			(183	)		4,668
Other income and deductions
Interest expense, net		(161	)		(318	)		(248	)		(123	)		(850	)
Equity in earnings (losses) of unconsolidated affiliates and investments		1			(7	)		(7	)		(93	)		(106	)
Other, net		155			58			45			202			460
Total other income and deductions		(5	)		(267	)		(210	)		(14	)		(496	)
Income (loss) from continuing operations before income taxes		3,387			245			737			(197	)		4,172
Income taxes		1,362			80			230			(226	)		1,446
Income from continuing operations		2,025			165			507			29			2,726
Income from discontinued operations		4			—			—			6			10
Net income	$	2,029		$	165		$	507		$	35		$	2,736
	Twelve Months Ended December 31, 2006
	Generation			ComEd			PECO			Other			Exelon Consolidated
Operating revenues	$	9,143		$	6,101		$	5,168		$	(4,757	)	$	15,655
Operating expenses
Purchased power		2,027			3,292			2,104			(4,740	)		2,683
Fuel		1,951			—			598			—			2,549
Operating and maintenance		2,305			745			628			190			3,868
Impairment of goodwill		—			776			—			—			776
Depreciation and amortization		279			430			710			68			1,487
Taxes other than income		185			303			262			21			771
Total operating expenses		6,747			5,546			4,302			(4,461	)		12,134
Operating income (loss)		2,396			555			866			(296	)		3,521
Other income and deductions
Interest expense, net		(159	)		(308	)		(266	)		(147	)		(880	)
Equity in losses of unconsolidated affiliates and investments		(9	)		(10	)		(9	)		(83	)		(111	)
Other, net		41			96			30			99			266
Total other income and deductions		(127	)		(222	)		(245	)		(131	)		(725	)
Income (loss) from continuing operations before income taxes		2,269			333			621			(427	)		2,796
Income taxes		866			445			180			(285	)		1,206
Income (loss) from continuing operations		1,403			(112	)		441			(142	)		1,590
Income (loss) from discontinued operations		4			—			—			(2	)		2
Net income (loss)	$	1,407		$	(112	)	$	441		$	(144	)	$	1,592

2

EXELON CORPORATION

Business Segment Comparative Statements of Operations

(unaudited)

(in millions)

	Generation
	Three Months Ended December 31,									Twelve Months Ended December 31,
	2007			2006			Variance			2007			2006			Variance
Operating revenues	$	2,568		$	2,074		$	494		$	10,749		$	9,143		$	1,606
Operating expenses
Purchased power		766			420			346			2,705			2,027			678
Fuel		372			467			(95	)		1,746			1,951			(205	)
Operating and maintenance		654			623			31			2,454			2,305			149
Depreciation and amortization		67			70			(3	)		267			279			(12	)
Taxes other than income		49			51			(2	)		185			185			—
Total operating expenses		1,908			1,631			277			7,357			6,747			610
Operating income		660			443			217			3,392			2,396			996
Other income and deductions
Interest expense, net		(62	)		(39	)		(23	)		(161	)		(159	)		(2	)
Equity in earnings (losses) of investments		—			—			—			1			(9	)		10
Other, net		87			11			76			155			41			114
Total other income and deductions		25			(28	)		53			(5	)		(127	)		122
Income from continuing operations before income taxes		685			415			270			3,387			2,269			1,118
Income taxes		341			170			171			1,362			866			496
Income from continuing operations		344			245			99			2,025			1,403			622
Income (loss) from discontinued operations		(1	)		—			(1	)		4			4			—
Net income	$	343		$	245		$	98		$	2,029		$	1,407		$	622
		ComEd
	Three Months Ended December 31,									Twelve Months Ended December 31,
	2007			2006			Variance			2007			2006			Variance
Operating revenues	$	1,436		$	1,381		$	55		$	6,104		$	6,101		$	3
Operating expenses
Purchased power		841			669			172			3,747			3,292			455
Operating and maintenance		313			101			212			1,091			745			346
Impairment of goodwill		—			—			—			—			776			(776	)
Depreciation and amortization		114			110			4			440			430			10
Taxes other than income		71			69			2			314			303			11
Total operating expenses		1,339			949			390			5,592			5,546			46
Operating income		97			432			(335	)		512			555			(43	)
Other income and deductions
Interest expense, net		(58	)		(78	)		20			(318	)		(308	)		(10	)
Equity in losses of unconsolidated affiliates		(2	)		(2	)		—			(7	)		(10	)		3
Other, net		48			6			42			58			96			(38	)
Total other income and deductions		(12	)		(74	)		62			(267	)		(222	)		(45	)
Income before income taxes		85			358			(273	)		245			333			(88	)
Income taxes		18			145			(127	)		80			445			(365	)
Net income (loss)	$	67		$	213		$	(146	)	$	165		$	(112	)	$	277

3

EXELON CORPORATION

Business Segment Comparative Statements of Operations

(unaudited)

(in millions)

	PECO
	Three Months Ended December 31,									Twelve Months Ended December 31,
	2007			2006			Variance			2007			2006			Variance
Operating revenues	$	1,385		$	1,235		$	150		$	5,613		$	5,168		$	445
Operating expenses
Purchased power		571			493			78			2,366			2,104			262
Fuel		194			154			40			617			598			19
Operating and maintenance		185			149			36			630			628			2
Depreciation and amortization		182			162			20			773			710			63
Taxes other than income		68			64			4			280			262			18
Total operating expenses		1,200			1,022			178			4,666			4,302			364
Operating income		185			213			(28	)		947			866			81
Other income and deductions
Interest expense, net		(60	)		(64	)		4			(248	)		(266	)		18
Equity in losses of unconsolidated affiliates		(2	)		(2	)		—			(7	)		(9	)		2
Other, net		10			14			(4	)		45			30			15
Total other income and deductions		(52	)		(52	)		—			(210	)		(245	)		35
Income before income taxes		133			161			(28	)		737			621			116
Income taxes		18			40			(22	)		230			180			50
Net income	$	115		$	121		$	(6	)	$	507		$	441		$	66
		Other (a)
	Three Months Ended December 31,									Twelve Months Ended December 31,
	2007			2006			Variance			2007			2006			Variance
Operating revenues	$	(835	)	$	(994	)	$	159		$	(3,550	)	$	(4,757	)	$	1,207
Operating expenses
Purchased power		(827	)		(991	)		164			(3,536	)		(4,740	)		1,204
Fuel		(2	)		—			(2	)		(3	)		—			(3	)
Operating and maintenance		23			6			17			114			190			(76	)
Depreciation and amortization		11			10			1			40			68			(28	)
Taxes other than income		6			6			—			18			21			(3	)
Total operating expenses		(789	)		(969	)		180			(3,367	)		(4,461	)		1,094
Operating loss		(46	)		(25	)		(21	)		(183	)		(296	)		113
Other income and deductions
Interest expense, net		(33	)		(36	)		3			(123	)		(147	)		24
Equity in losses of unconsolidated affiliates and investments		(13	)		(33	)		20			(93	)		(83	)		(10	)
Other, net		91			30			61			202			99			103
Total other income and deductions		45			(39	)		84			(14	)		(131	)		117
Loss from continuing operations before income taxes		(1	)		(64	)		63			(197	)		(427	)		230
Income taxes		(37	)		(78	)		41			(226	)		(285	)		59
Income (loss) from continuing operations		36			14			22			29			(142	)		171
Income (loss) from discontinued operations		1			(1	)		2			6			(2	)		8
Net income (loss)	$	37		$	13		$	24		$	35		$	(144	)	$	179

(a) Other includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities, Exelon Enterprises Company, LLC and other financing and investment activities, including investments in synthetic fuel-producing facilities.

4

EXELON CORPORATION

Consolidated Balance Sheets

(unaudited)

(in millions)

	December 31, 2007			December 31, 2006
Current assets
Cash and cash equivalents	$	311		$	224
Restricted cash and investments		118			58
Accounts receivable, net
Customer		2,041			1,747
Other		611			462
Mark-to-market derivative assets		445			1,418
Inventories, net, at average cost
Fossil fuel		252			300
Materials and supplies		471			431
Other		802			352
Total current assets		5,051			4,992
Property, plant and equipment, net		24,153			22,775
Deferred debits and other assets
Regulatory assets		5,133			5,808
Nuclear decommissioning trust funds		6,823			6,415
Investments		731			810
Goodwill		2,625			2,694
Mark-to-market derivative assets		117			171
Other		1,261			654
Total deferred debits and other assets		16,690			16,552
Total assets	$	45,894		$	44,319
Liabilities and shareholders’ equity
Current liabilities
Short-term borrowings	$	616		$	305
Long-term debt due within one year		605			248
Long-term debt to ComEd Transitional Funding Trust and PECO Energy Transition Trust due within one year		501			581
Accounts payable		1,450			1,382
Mark-to-market derivative liabilities		599			1,015
Accrued expenses		1,240			1,180
Other		984			1,084
Total current liabilities		5,995			5,795
Long-term debt		9,915			8,896
Long-term debt to ComEd Transitional Funding Trust and PECO Energy Transition Trust		1,505			2,470
Long-term debt to other financing trusts		545			545
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits		5,081			5,340
Asset retirement obligations		3,812			3,780
Pension obligations		777			747
Non-pension postretirement benefits obligations		1,717			1,817
Spent nuclear fuel obligation		997			950
Regulatory liabilities		3,301			3,025
Mark-to-market derivative liabilities		465			78
Other		1,560			782
Total deferred credits and other liabilities		17,710			16,519
Total liabilities		35,670			34,225
Preferred securities of subsidiary		87			87
Shareholders’ equity
Common stock		8,579			8,314
Treasury stock, at cost		(1,838	)		(630	)
Retained earnings		4,930			3,426
Accumulated other comprehensive loss, net		(1,534	)		(1,103	)
Total shareholders’ equity		10,137			10,007
Total liabilities and shareholders’ equity	$	45,894		$	44,319

5

EXELON CORPORATION

Consolidated Statements of Cash Flows

(unaudited)

(in millions)

	Twelve Months Ended December 31,
	2007			2006
Cash flows from operating activities
Net income	$	2,736		$	1,592
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion, including nuclear fuel		2,183			2,132
Deferred income taxes and amortization of investment tax credits		(104	)		73
Net realized and unrealized mark-to-market transactions		102			(83	)
Impairment charges		—			894
Other non-cash operating activities		664			197
Changes in assets and liabilities:
Accounts receivable		(661	)		(62	)
Inventories		9			(59	)
Accounts payable, accrued expenses and other current liabilities		330			67
Counterparty collateral asset		(246	)		259
Counterparty collateral liability		(270	)		172
Income taxes		160			69
Restricted cash		(15	)		—
Pension and non-pension postretirement benefit contributions		(204	)		(180	)
Other assets and liabilities		(188	)		(236	)
Net cash flows provided by operating activities		4,496			4,835
Cash flows from investing activities
Capital expenditures		(2,674	)		(2,418	)
Proceeds from nuclear decommissioning trust fund sales		7,312			4,793
Investment in nuclear decommissioning trust funds		(7,527	)		(5,081	)
Proceeds from sale of investments		95			2
Change in restricted cash		(45	)		(9	)
Other investing activities		(70	)		(49	)
Net cash flows used in investing activities		(2,909	)		(2,762	)
Cash flows from financing activities
Issuance of long-term debt		1,621			1,370
Retirement of long-term debt		(262	)		(402	)
Retirement of long-term debt to financing affiliates		(1,020	)		(910	)
Change in short-term debt		311			(685	)
Retirement of short-term debt		—			(300	)
Dividends paid on common stock		(1,180	)		(1,071	)
Proceeds from employee stock plans		215			184
Purchase of treasury stock		(1,208	)		(186	)
Purchase of forward contract in relation to certain treasury stock		(79	)		—
Other financing activities		102			11
Net cash flows used in financing activities		(1,500	)		(1,989	)
Increase in cash and cash equivalents		87			84
Cash and cash equivalents at beginning of period		224			140
Cash and cash equivalents at end of period	$	311		$	224

6

EXELON CORPORATION

Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Consolidated Statements of Operations

(unaudited)

(in millions, except per share data)

	Three Months Ended December 31, 2007							Three Months Ended December 31, 2006
	GAAP (a)		Adjustments			Adjusted Non-GAAP		GAAP (a)		Adjustments			Adjusted Non-GAAP
Operating revenues	$	4,554	$	92	(b),(c),(d),(e)	$	4,646	$	3,696	$	—		$	3,696
Operating expenses
Purchased power		1,351		(205)	(b),(e),(f)		1,146		591		38	(b)		629
Fuel		564		41	(b)		605		621		(63)	(b)		558
Operating and maintenance		1,175		12	(g)		1,187		879		134	(b),(g),(i),(j)		1,013
Depreciation and amortization		374		—			374		352		—			352
Taxes other than income		194		—			194		190		—			190
Total operating expenses		3,658		(152)			3,506		2,633		109			2,742
Operating income		896		244			1,140		1,063		(109)			954
Other income and deductions
Interest expense, net		(213)		4	(h)		(209)		(217)		2	(g)		(215)
Equity in losses of unconsolidated affiliates and investments		(17)		12	(g)		(5)		(37)		33	(g)		(4)
Other, net		236		(75)	(g)		161		61		(21)	(b),(g),(k)		40
Total other income and deductions		6		(59)			(53)		(193)		14			(179)
Income from continuing operations before income taxes		902		185			1,087		870		(95)			775
Income taxes		340		70	(b),(c),(d),(e),(f),(g),(h)		410		277		10	(b),(g),(i),(j),(k)		287
Income from continuing operations	$	562	$	115		$	677	$	593	$	(105)		$	488
Loss from discontinued operations		—		—			—		(1)		—			(1)
Net income	$	562	$	115		$	677	$	592	$	(105)		$	487
Earnings per average common share
Basic:
Income from continuing operations	$	0.85	$	0.18		$	1.03	$	0.88	$	(0.15)		$	0.73
Net income	$	0.85	$	0.18		$	1.03	$	0.88	$	(0.15)		$	0.73
Diluted:
Income from continuing operations	$	0.84	$	0.18		$	1.02	$	0.87	$	(0.15)		$	0.72
Net income	$	0.84	$	0.18		$	1.02	$	0.87	$	(0.15)		$	0.72
Average common shares outstanding
Basic		661					661		672					672
Diluted		666					666		677					677
Effect of adjustments on earnings per average diluted common share recorded in accordance with GAAP:
Mark-to-market (b)			$	0.03						$	0.03
2007 Illinois electric rate settlement (c)				0.28							—
City of Chicago settlement (d)				0.02							—
Termination of State Line PPA (e)				(0.19)							—
Georgia Power tolling agreement (f)				0.11							—
Investments in synthetic fuel-producing facilities (g)				(0.03)							(0.04)
Non-cash deferred tax items (h)				(0.04)							—
Recovery of severance costs at ComEd (i)				—							(0.14)
Total adjustments			$	0.18						$	(0.15)

(a) Results reported in accordance with accounting principles generally accepted in the United States (GAAP).

(b) Adjustment to exclude the mark-to-market impact of Exelon’s economic hedging activities.

(c) Adjustment to exclude the impact of the 2007 Illinois electric rate settlement.

(d) Adjustment to exclude the 2007 costs associated with ComEd’s settlement agreement with the City of Chicago.

(e) Adjustment to exclude the income associated with the termination of Generation’s power purchase agreement (PPA) with State Line Energy, L.L.C. (State Line).

(f) Adjustment to exclude the loss associated with Generation’s tolling agreement with Georgia Power related to the contract with Tenaska Georgia Partners, LP (Tenaska).

(g) Adjustment to exclude the financial impact of Exelon’s investments in synthetic fuel-producing facilities, including the impact of mark-to-market gains (losses) associated with the related derivatives.

(h) Adjustment to exclude non-cash deferred tax items.

(i) Adjustment to exclude a one-time benefit to recover previously incurred severance costs approved by the December 2006 amended Illinois Commerce Commission (ICC) rate order.

(j) Adjustment to exclude severance charges in 2006.

(k) Adjustment to exclude an impairment charge related to Generation’s investments in Termoeléctrica del Golfo (TEG) and Termoeléctrica Peñoles (TEP), the sale of which occurred in February 2007.

7

EXELON CORPORATION

Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Consolidated Statements of Operations

(unaudited)

(in millions, except per share data)

	Twelve Months Ended December 31, 2007							Twelve Months Ended December 31, 2006
	GAAP (a)		Adjustments			Adjusted Non-GAAP		GAAP (a)		Adjustments			Adjusted Non-GAAP
Operating revenues	$	18,916	$	236	(b),(c),(d),(e)	$	19,152	$	15,655	$	5	(b)	$	15,660
Operating expenses
Purchased power		5,282		(378)	(b),(e),(f)		4,904		2,683		179	(b)		2,862
Fuel		2,360		81	(b)		2,441		2,549		(77)	(b)		2,472
Operating and maintenance		4,289		(72)	(c),(g),(h)		4,217		3,868		23	(b),(g),(h),(l),(m),(n)		3,891
Impairment of goodwill		—		—			—		776		(776)	(o)		—
Depreciation and amortization		1,520		—			1,520		1,487		(37)	(g),(l)		1,450
Taxes other than income		797		—			797		771		—			771
Total operating expenses		14,248		(369)			13,879		12,134		(688)			11,446
Operating income		4,668		605			5,273		3,521		693			4,214
Other income and deductions
Interest expense, net		(850)		7	(g),(i)		(843)		(880)		16	(g),(k)		(864)
Equity in losses of unconsolidated affiliates and investments		(106)		93	(g)		(13)		(111)		83	(g)		(28)
Other, net		460		(196)	(g),(j)		264		266		(151)	(b),(g),(l),(p),(q)		115
Total other income and deductions		(496)		(96)			(592)		(725)		(52)			(777)
Income from continuing operations before income taxes		4,172		509			4,681		2,796		641			3,437
Income taxes		1,446		317	(b),(c),(d),(e),(f),(g),(h),(i),(j)		1,763		1,206		54	(b),(g),(h),(k),(l),(m),(n),(p),(q)		1,260
Income from continuing operations		2,726		192			2,918		1,590		587			2,177
Income (loss) from discontinued operations		10		(5)	(k)		5		2		(4)	(k)		(2)
Net income	$	2,736	$	187		$	2,923	$	1,592	$	583		$	2,175
Earnings per average common share
Basic:
Income from continuing operations	$	4.06	$	0.29		$	4.35	$	2.37	$	0.88		$	3.25
Income (loss) from discontinued operations		0.02		(0.01)			0.01		—		—			—
Net income	$	4.08	$	0.28		$	4.36	$	2.37	$	0.88		$	3.25
Diluted:
Income from continuing operations	$	4.03	$	0.28		$	4.31	$	2.35	$	0.87		$	3.22
Income (loss) from discontinued operations		0.02		(0.01)			0.01		—		—			—
Net income	$	4.05	$	0.27		$	4.32	$	2.35	$	0.87		$	3.22
Average common shares outstanding
Basic		670					670		670					670
Diluted		676					676		676					676
Effect of adjustments on earnings per average diluted common share recorded in accordance with GAAP:
Mark-to-market (b)			$	0.15						$	(0.09)
2007 Illinois electric rate settlement (c)				0.41							—
City of Chicago settlement (d)				0.02							—
Termination of State Line PPA (e)				(0.19)							—
Georgia Power tolling agreement (f)				0.11							—
Investments in synthetic fuel-producing facilities (g)				(0.14)							0.04
Nuclear decommissioning obligation reduction (h)				(0.03)							(0.13)
Non-cash deferred tax items (i)				(0.04)							—
Sale of Generation’s investments in TEG and TEP (j)				(0.01)							—
Settlement of a tax matter at Generation related to Sithe (k)				(0.01)							—
Charges associated with Exelon’s now terminated merger with PSEG (l)				—							0.09
2006 severance charges (m)				—							0.03
Recovery of severance costs at ComEd (n)				—							(0.14)
2006 impairment of ComEd’s goodwill (o)				—							1.15
Recovery of debt costs at ComEd (p)				—							(0.08)
Total adjustments			$	0.27						$	0.87

(a) Results reported in accordance with GAAP.

(b) Adjustment to exclude the mark-to-market impact of Exelon’s economic hedging activities.

(c) Adjustment to exclude the impact of the 2007 Illinois electric rate settlement.

(d) Adjustment to exclude the 2007 costs associated with ComEd’s settlement agreement with the City of Chicago.

(e) Adjustment to exclude the income associated with the termination of Generation’s PPA with State Line.

(f) Adjustment to exclude the loss associated with Generation’s tolling agreement with Georgia Power related to the contract with Tenaska.

(g) Adjustment to exclude the financial impact of Exelon’s investments in synthetic fuel-producing facilities, including the impact of mark-to-market gains (losses) associated with the related derivatives.

(h) Adjustment to exclude the decrease in Generation’s nuclear decommissioning obligation liability primarily related to the AmerGen Energy Company, LLC (AmerGen) nuclear plants.

(i) Adjustment to exclude non-cash deferred tax items.

(j) Adjustment to exclude the gain related to the sale of Generation’s ownership interest in TEG and TEP.

(k) Adjustment to exclude the settlement of separate tax matters at Generation related to Sithe in 2006 and 2007.

(l) Adjustment to exclude certain costs associated with Exelon’s proposed merger with Public Service Enterprise Group Incorporated (PSEG), which was terminated in September 2006.

(m) Adjustment to exclude severance charges in 2006.

(n) Adjustment to exclude a one-time benefit to recover previously incurred severance costs approved by the December 2006 amended ICC rate order.

(o) Adjustment to exclude the impairment of ComEd’s goodwill in 2006.

(p) Adjustment to exclude the one-time benefit to recover previously incurred debt costs approved by the July 2006 ICC rate order.

(q) Adjustment to exclude an impairment charge related to Generation’s investments in TEG and TEP, the sale of which occurred in February 2007.

8

EXELON CORPORATION

Reconciliation of Adjusted (non-GAAP) Operating Earnings

Per Diluted Share to GAAP Earnings Per Diluted Share

Three Months Ended December 31, 2007 and 2006

2006 GAAP Earnings per Diluted Share	$	0.87
2006 Adjusted (non-GAAP) Operating Earnings Adjustments:
Mark-to-Market (1)		0.03
Investments in Synthetic Fuel-Producing Facilities (2)		(0.04	)
Recovery of Severance Costs at ComEd (3)		(0.14	)
2006 Adjusted (non-GAAP) Operating Earnings		0.72
Year Over Year Effects on Earnings:
Generation Energy Margins, Excluding Mark-to-Market (4)		0.44
ComEd Energy Margins:
Weather (5)		0.02
End of Regulatory Transition Period (6)		(0.16	)
Other Energy Delivery (7)		0.07
PECO Energy Margins:
Weather (8)		0.03
Pension and Non-Pension Postretirement Benefits Expense (9)		(0.01	)
Bad Debt (10)		(0.04	)
Labor and Contracting (11)		(0.07	)
Storm Costs (12)		0.01
Exelon Foundation Contribution (13)		(0.05	)
Nuclear Plant Development Costs (14)		(0.04	)
Planned Nuclear Refueling Outages (15)		(0.01	)
Other Operating and Maintenance Expense (16)		0.01
Depreciation and Amortization (17)		(0.03	)
Nuclear Decommissioning Trust Fund Rebalancing (18)		0.06
Tax Method Change - Overhead Costs (19)		0.06
Income Taxes (20)		0.02
Taxes Other Than Income and Other (21)		(0.03	)
Share Differential (22)		0.02
2007 Adjusted (non-GAAP) Operating Earnings		1.02
2007 Adjusted (non-GAAP) Operating Earnings Adjustments:
Mark-to-Market (1)		(0.03	)
Investments in Synthetic Fuel-Producing Facilities (2)		0.03
2007 Illinois Electric Rate Settlement (23)		(0.28	)
City of Chicago Settlement (24)		(0.02	)
Termination of State Line PPA (25)		0.19
Georgia Power Tolling Agreement (26)		(0.11	)
Non-Cash Deferred Tax Items (27)		0.04
2007 GAAP Earnings per Diluted Share	$	0.84

(1) Reflects the mark-to-market impact of Exelon’s economic hedging activities.

(2) Reflects the financial impact of Exelon’s investments in synthetic fuel-producing facilities, including the impact of mark-to-market gains (losses) associated with the related derivatives.

(3) Reflects a one-time benefit approved by the December 2006 amended ICC rate order to recover previously incurred severance costs.

(4) Reflects higher average margins primarily due to the end of the below-market PPA with ComEd at year-end 2006 and the contractual increase in prices associated with Generation’s PPA with PECO.

(5) Reflects a favorable variance for weather conditions in the ComEd service territory.

(6) Reflects reduced earnings at ComEd primarily due to the end of the Illinois regulatory transition period.

(7) Reflects increased transmission revenue as a result of the 2007 transmission rate case and increased pricing for delivery service due to the 2006 ICC rate order.

(8) Reflects a favorable variance for weather conditions in the PECO service territory.

(9) Reflects increased pension and non-pension postretirement benefits expense primarily due to changes in actuarial assumptions for 2007.

(10) Reflects increased bad debt expense at ComEd and PECO.

(11) Primarily reflects labor-related inflation and increased costs at generating facilities.

(12) Reflects higher 2006 storm costs in the ComEd and PECO service territories.

(13) Reflects a charitable contribution to the Exelon Foundation.

(14) Reflects the costs associated with the possible construction of a new nuclear plant in Texas.

(15) Reflects increased planned nuclear refueling outage costs, excluding the Salem Generating Station (Salem).

(16) Primarily reflects nuclear refueling outage costs at Salem in 2006.

(17) Reflects increased depreciation and amortization primarily due to increased competitive transition charge (CTC) amortization at PECO.

(18) Reflects the impact on net income of gains realized in 2007 on AmerGen’s decommissioning trust fund investments related to changes to the investment strategy.

(19) Reflects a favorable income tax benefit associated with Exelon’s method of capitalizing overhead costs.

(20) Primarily reflects a favorable income tax settlement at ComEd in 2007.

(21) Primarily reflects higher interest expense at Exelon.

(22) Reflects the impact on earnings per share due to a change in Exelon’s diluted common shares outstanding.

(23) Reflects the impact of the 2007 Illinois electric rate settlement.

(24) Reflects the 2007 costs associated with ComEd’s settlement agreement with the City of Chicago.

(25) Reflects the income associated with the termination of Generation’s PPA with State Line.

(26) Reflects the loss associated with Generation’s tolling agreement with Georgia Power related to the contract with Tenaska.

(27) Reflects non-cash deferred tax items.

9

EXELON CORPORATION

Reconciliation of Adjusted (non-GAAP) Operating Earnings

to GAAP Earnings By Business Segment (in millions)

Three Months Ended December 31, 2007 and 2006

	Generation			ComEd			PECO			Other			Exelon
2006 GAAP Earnings	$	245		$	213		$	121		$	13		$	592
2006 Adjusted (non-GAAP) Operating Earnings (Loss) Adjustments:
Mark-to-Market (1)		17			—			—			—			17
Investments in Synthetic Fuel-Producing Facilities (2)		—			—			—			(31	)		(31	)
2006 Severance Charges (3)		1			—			1			1			3
Recovery of Severance Costs at ComEd (4)		—			(95	)		—			—			(95	)
Impairment of Generation’s Investments in TEG and TEP (5)		1			—			—			—			1
2006 Adjusted (non-GAAP) Operating Earnings (Loss)		264			118			122			(17	)		487
Year Over Year Effects on Earnings:
Generation Energy Margins, Excluding Mark-to-Market (6)		291			—			—			—			291
ComEd and PECO Energy Margins:
Weather (7)		—			10			23			—			33
End of Regulatory Transition Period (8)		—			(109	)		—			—			(109	)
Other Energy Delivery (9)		—			46			(1	)		—			45
Pension and Non-Pension Postretirement Benefits Expense (10)		(4	)		(1	)		1			—			(4	)
Bad Debt (11)		(2	)		(10	)		(15	)		—			(27	)
Labor and Contracting (12)		(32	)		(12	)		(7	)		—			(51	)
Storm Costs (13)		—			2			2			—			4
Exelon Foundation Contribution (14)		—			—			—			(32	)		(32	)
Nuclear Plant Development Costs (15)		(23	)		—			—			—			(23	)
Planned Nuclear Refueling Outages (16)		(8	)		—			—			—			(8	)
Other Operating and Maintenance Expense (17)		11			1			(3	)		—			9
Depreciation and Amortization (18)		—			(3	)		(13	)		—			(16	)
Nuclear Decommissioning Trust Fund Rebalancing (19)		38			—			—			—			38
Tax Method Change - Overhead Costs (20)		(38	)		36			33			9			40
Income Taxes (21)		26			14			(21	)		(3	)		16
Taxes Other Than Income and Other (22)		(4	)		(8	)		(6	)		2			(16	)
2007 Adjusted (non-GAAP) Operating Earnings (Loss)		519			84			115			(41	)		677
2007 Adjusted (non-GAAP) Operating Earnings (Loss) Adjustments:
Mark-to-Market (1)		(21	)		2			—			(3	)		(22	)
Investments in Synthetic Fuel-Producing Facilities (2)		—			—			—			18			18
2007 Illinois Electric Rate Settlement (23)		(179	)		(5	)		—			—			(184	)
City of Chicago Settlement (24)		—			(14	)		—			—			(14	)
Termination of State Line PPA (25)		130			—			—			—			130
Georgia Power Tolling Agreement (26)		(72	)		—			—			—			(72	)
Non-Cash Deferred Tax Items (27)		(34	)		—			—			63			29
2007 GAAP Earnings	$	343		$	67		$	115		$	37		$	562

(1) Reflects the mark-to-market impact of Exelon’s economic hedging activities.

(2) Reflects the financial impact of Exelon’s investments in synthetic fuel-producing facilities, including the impact of mark-to-market gains (losses) associated with the related derivatives.

(3) Reflects severance charges in 2006.

(4) Reflects a one-time benefit approved by the December 2006 amended ICC rate order to recover previously incurred severance costs.

(5) Reflects an impairment charge related to Generation’s investments in TEG and TEP, the sale of which occurred in February 2007.

(6) Reflects higher average margins primarily due to the end of the below-market PPA with ComEd at year-end 2006 and the contractual increase in prices associated with Generation’s PPA with PECO.

(7) Reflects favorable variance for weather conditions in the ComEd and PECO service territories.

(8) Reflects reduced earnings at ComEd primarily due to the end of the Illinois regulatory transition period.

(9) Reflects increased transmission revenue as a result of the 2007 transmission rate case and increased pricing for delivery service due to the 2006 ICC rate order.

(10) Reflects increased pension and non-pension postretirement benefits expense primarily due to changes in actuarial assumptions for 2007.

(11) Reflects increased bad debt expense at ComEd and PECO.

(12) Primarily reflects labor-related inflation and increased costs at generating facilities.

(13) Reflects higher 2006 storm costs in the ComEd and PECO service territories.

(14) Reflects a charitable contribution to the Exelon Foundation.

(15) Reflects the costs associated with the possible construction of a new nuclear plant in Texas.

(16) Reflects increased planned nuclear refueling outage costs, excluding Salem.

(17) Primarily reflects nuclear refueling outage costs at Salem in 2006.

(18) Reflects increased depreciation and amortization primarily due to increased CTC amortization at PECO.

(19) Reflects the impact on net income of gains realized in 2007 on AmerGen’s decommissioning trust fund investments related to changes to the investment strategy.

(20) Reflects a favorable income tax benefit associated with Exelon’s method of capitalizing overhead costs.

(21) Primarily reflects a favorable income tax settlement at ComEd in 2007.

(22) Primarily reflects higher interest expense at Exelon.

(23) Reflects the impact of the 2007 Illinois electric rate settlement.

(24) Reflects the 2007 costs associated with ComEd’s settlement agreement with the City of Chicago.

(25) Reflects the income associated with the termination of Generation’s PPA with State Line.

(26) Reflects the loss associated with Generation’s tolling agreement with Georgia Power related to the contract with Tenaska.

(27) Reflects non-cash deferred tax items.

10

EXELON CORPORATION

Reconciliation of Adjusted (non-GAAP) Operating Earnings

Per Diluted Share to GAAP Earnings Per Diluted Share

Twelve Months Ended December 31, 2007 and 2006

2006 GAAP Earnings per Diluted Share	$	2.35
2006 Adjusted (non-GAAP) Operating Earnings Adjustments:
Mark-to-Market (1)		(0.09	)
Investments in Synthetic Fuel-Producing Facilities (2)		0.04
Nuclear Decommissioning Obligation Reduction (3)		(0.13	)
Charges Associated with Exelon’s Now Terminated Merger with PSEG (4)		0.09
2006 Severance Charges (5)		0.03
Recovery of Severance Costs at ComEd (6)		(0.14	)
Impairment of ComEd’s Goodwill (7)		1.15
Recovery of Debt Costs at ComEd (8)		(0.08	)
2006 Adjusted (non-GAAP) Operating Earnings		3.22
Year Over Year Effects on Earnings:
Generation Energy Margins, Excluding Mark-to-Market (9)		1.66
ComEd Energy Margins:
Weather (10)		0.05
End of Regulatory Transition Period (11)		(0.61	)
Other Energy Delivery (12)		0.20
PECO Energy Margins:
Weather (13)		0.08
Other Energy Delivery (14)		0.07
PJM Settlement (15)		0.04
Pension and Non-Pension Postretirement Benefits Expense (16)		(0.03	)
Bad Debt (17)		(0.04	)
Labor and Contracting (18)		(0.19	)
Storm Costs (19)		0.02
Recovery of Environmental Costs at ComEd (20)		(0.04	)
Exelon Foundation Contribution (21)		(0.05	)
Nuclear Plant Development Costs (22)		(0.04	)
Planned Nuclear Refueling Outages (23)		0.03
Other Operating and Maintenance Expense (24)		(0.04	)
Depreciation and Amortization (25)		(0.07	)
Reduction of a Liability Related to Property Taxes (26)		0.03
Nuclear Decommissioning Trust Fund Rebalancing (27)		0.06
Tax Method Change - Overhead Costs (28)		0.06
Income Taxes (29)		(0.05	)
Taxes Other Than Income and Other (30)		(0.04	)
2007 Adjusted (non-GAAP) Operating Earnings		4.32
2007 Adjusted (non-GAAP) Operating Earnings Adjustments:
Mark-to-Market (1)		(0.15	)
Investments in Synthetic Fuel-Producing Facilities (2)		0.14
Nuclear Decommissioning Obligation Reduction (3)		0.03
2007 Illinois Electric Rate Settlement (31)		(0.41	)
City of Chicago Settlement (32)		(0.02	)
Termination of State Line PPA (33)		0.19
Georgia Power Tolling Agreement (34)		(0.11	)
Sale of Generation’s investments in TEG and TEP (35)		0.01
Settlement of a Tax Matter at Generation Related to Sithe (36)		0.01
Non-Cash Deferred Tax Items (37)		0.04
2007 GAAP Earnings per Diluted Share	$	4.05

(1) Reflects the mark-to-market impact of Exelon’s economic hedging activities.

(2) Reflects the financial impact of Exelon’s investments in synthetic fuel-producing facilities, including the impact of mark-to-market gains (losses) associated with the related derivatives.

(3) Reflects a decrease in Generation’s nuclear decommissioning obligation liability primarily related to the AmerGen nuclear plants.

(4) Reflects certain costs incurred in connection with Exelon’s proposed merger with PSEG, which was terminated in September 2006.

(5) Reflects severance charges in 2006.

(6) Reflects a one-time benefit approved by the December 2006 amended ICC rate order to recover previously incurred severance costs.

(7) Reflects impairment of ComEd’s goodwill in 2006.

(8) Reflects a one-time benefit approved by the July 2006 ICC rate order to recover previously incurred debt expenses to retire debt early.

(9) Reflects higher average margins primarily due to the end of the below-market PPA with ComEd at year-end 2006, higher nuclear output reflecting fewer outage days and the contractual increase in prices associated with Generation’s PPA with PECO.

(10) Reflects a favorable variance for weather conditions in the ComEd service territory.

(11) Reflects reduced earnings at ComEd primarily due to the end of the Illinois regulatory transition period.

(12) Reflects increased transmission revenue as a result of the 2007 transmission rate case, increased pricing for delivery service due to the 2006 ICC rate order and higher electric delivery volume (excluding the impact of weather).

(13) Reflects a favorable variance for weather conditions in the PECO service territory.

(14) Reflects increased revenues at PECO primarily due to higher electric delivery volume (excluding the impact of weather) and increased late payment fees at PECO.

(15) Reflects the favorable PJM Interconnection, LLC (PJM) billing settlement with PPL Electric (PPL) approved by the Federal Energy Regulatory Commission (FERC).

(16) Reflects increased pension and non-pension postretirement benefits expense primarily due to changes in actuarial assumptions for 2007.

(17) Reflects increased bad debt expense at ComEd and PECO.

(18) Primarily reflects labor-related inflation and increased costs at generating facilities.

(19) Reflects higher 2006 storm costs in the PECO service territory, partially offset by increased storm costs in the ComEd service territory in 2007.

(20) Reflects a one-time benefit approved by the July 2006 ICC rate order to recover previously incurred environmental expenses associated with manufactured gas plants.

(21) Reflects a charitable contribution to the Exelon Foundation.

(22) Reflects the costs associated with the possible construction of a new nuclear plant in Texas.

(23) Reflects decreased planned nuclear refueling outage costs, excluding Salem.

(24) Primarily reflects severance charges in 2007, one-time settlements at PECO and higher Nuclear Regulatory Commission (NRC) fees.

(25) Reflects increased depreciation and amortization primarily due to increased CTC amortization at PECO.

(26) Reflects a reduction of a liability associated with PECO’s property taxes under the Pennsylvania Public Utility Realty Tax Act (PURTA).

(27) Reflects the impact on net income of gains realized in 2007 on AmerGen’s decommissioning trust fund investments related to changes to the investment strategy.

(28) Reflects a favorable income tax benefit associated with Exelon’s method of capitalizing overhead costs.

(29) Primarily reflects the impact on 2006 net income of a research and development tax credit refund and an investment tax credit (ITC) refund at PECO as well as changes in income tax legislation in Pennsylvania, partially offset by a favorable income tax settlement at ComEd in 2007.

(30) Reflects higher utility revenue taxes at ComEd and PECO and higher interest expense at ComEd, partially offset by lower interest expense at PECO.

(31) Reflects the impact of the 2007 Illinois electric rate settlement.

(32) Reflects the 2007 costs associated with ComEd’s settlement agreement with the City of Chicago.

(33) Reflects the income associated with the termination of Generation’s PPA with State Line.

(34) Reflects the loss associated with Generation’s tolling agreement with Georgia Power related to the contract with Tenaska.

(35) Reflects the gain related to the sale of Generation’s ownership interest in TEG and TEP.

(36) Reflects the settlement of a tax matter at Generation related to Sithe.

(37) Reflects non-cash deferred tax items.

11

EXELON CORPORATION

Reconciliation of Adjusted (non-GAAP) Operating Earnings

to GAAP Earnings By Business Segment (in millions)

Twelve Months Ended December 31, 2007 and 2006

	Generation			ComEd			PECO			Other			Exelon
2006 GAAP Earnings (Loss)	$	1,407		$	(112	)	$	441		$	(144	)	$	1,592
2006 Adjusted (non-GAAP) Operating Earnings (Loss) Adjustments:
Mark-to-Market (1)		(61	)		3			—			—			(58	)
Investments in Synthetic Fuel-Producing Facilities (2)		—			—			—			24			24
Nuclear Decommissioning Obligation Reduction (3)		(89	)		—			—			—			(89	)
Charges Associated with Exelon’s Now Terminated Merger with PSEG (4)		8			4			10			36			58
2006 Severance Charges (5)		9			4			4			1			18
Recovery of Severance Costs at ComEd (6)		—			(95	)		—			—			(95	)
Impairment of ComEd’s Goodwill (7)		—			776			—			—			776
Recovery of Debt Costs at ComEd (8)		—			(52	)		—			—			(52	)
Impairment of Generation’s Investments in TEG and TEP (9)		1			—			—			—			1
2006 Adjusted (non-GAAP) Operating Earnings (Loss)		1,275			528			455			(83	)		2,175
Year Over Year Effects on Earnings:
Generation Energy Margins, Excluding Mark-to-Market (10)		1,125			—			—			—			1,125
ComEd and PECO Energy Margins:
Weather (11)		—			35			55			—			90
End of Regulatory Transition Period (12)		—			(415	)		—			—			(415	)
Other Energy Delivery (13)		—			137			48			—			185
PJM Settlement (14)		20			—			7			—			27
Pension and Non-Pension Postretirement Benefits Expense (15)		(15	)		(8	)		1			—			(22	)
Bad Debt (16)		(2	)		(15	)		(9	)		—			(26	)
Labor and Contracting (17)		(79	)		(28	)		(23	)		—			(130	)
Storm Costs (18)		—			(11	)		26			—			15
Recovery of Environmental Costs at ComEd (19)		—			(24	)		—			—			(24	)
Exelon Foundation Contribution (20)		—			—			—			(32	)		(32	)
Nuclear Plant Development Costs (21)		(30	)		—			—			—			(30	)
Planned Nuclear Refueling Outages (22)		18			—			—			—			18
Other Operating and Maintenance Expense (23)		(1	)		(17	)		(8	)		—			(26	)
Depreciation and Amortization (24)		4			(6	)		(48	)		—			(50	)
Reduction of a Liability Related to Property Taxes (25)		—			—			23			—			23
Nuclear Decommissioning Trust Fund Rebalancing (26)		38			—			—			—			38
Tax Method Change - Overhead Costs (27)		(38	)		36			33			9			40
Income Taxes (28)		14			15			(45	)		(15	)		(31	)
Taxes Other Than Income and Other (29)		2			(27	)		(8	)		6			(27	)
2007 Adjusted (non-GAAP) Operating Earnings (Loss)		2,331			200			507			(115	)		2,923
2007 Adjusted (non-GAAP) Operating Earnings (Loss) Adjustments:
Mark-to-Market (1)		(104	)		3			—			—			(101	)
Investments in Synthetic Fuel-Producing Facilities (2)		—			—			—			87			87
Nuclear Decommissioning Obligation Reduction (3)		18			—			—			—			18
2007 Illinois Electric Rate Settlement (30)		(256	)		(24	)		—			—			(280	)
City of Chicago Settlement (31)		—			(14	)		—			—			(14	)
Termination of State Line PPA (32)		130			—			—			—			130
Georgia Power Tolling Agreement (33)		(72	)		—			—			—			(72	)
Sale of Generation’s investments in TEG and TEP (34)		11			—			—			—			11
Settlement of a Tax Matter at Generation Related to Sithe (35)		5			—			—			—			5
Non-Cash Deferred Tax Items (36)		(34	)		—			—			63			29
2007 GAAP Earnings	$	2,029		$	165		$	507		$	35		$	2,736

(1) Reflects the mark-to-market impact of Exelon’s economic hedging activities.

(2) Reflects the financial impact of Exelon’s investments in synthetic fuel-producing facilities, including the impact of mark-to-market gains (losses) associated with the related derivatives.

(3) Reflects a decrease in Generation’s nuclear decommissioning obligation liability primarily related to the AmerGen nuclear plants.

(4) Reflects certain integration costs incurred in connection with Exelon’s proposed merger with PSEG, which was terminated in September 2006.

(5) Reflects severance charges in 2006.

(6) Reflects a one-time benefit approved by the December 2006 amended ICC rate order to recover previously incurred severance costs.

(7) Reflects impairment of ComEd’s goodwill in 2006.

(8) Reflects a one-time benefit approved by the July 2006 ICC rate order to recover previously incurred debt expenses to retire debt early.

(9) Reflects an impairment charge related to Generation’s investments in TEG and TEP, the sale of which occurred in February 2007.

(10) Reflects higher average margins primarily due to the end of the below-market PPA with ComEd at year-end 2006, higher nuclear output reflecting fewer outage days and the contractual increase in prices associated with Generation’s PPA with PECO.

(11) Reflects favorable variance for weather conditions in the ComEd and PECO service territories.

(12) Reflects reduced earnings at ComEd primarily due to the end of the Illinois regulatory transition period.

(13) Reflects increased transmission revenue as a result of ComEd’s 2007 transmission rate case, increased pricing for delivery service at ComEd as a result of the 2006 ICC rate order, higher electric delivery volume at ComEd and PECO (excluding the impact of weather) and increased late payment fees at PECO.

(14) Reflects the favorable PJM billing settlement with PPL approved by FERC.

(15) Reflects increased pension and non-pension postretirement benefits expense primarily due to changes in actuarial assumptions for 2007.

(16) Reflects increased bad debt expense at ComEd and PECO.

(17) Primarily reflects labor-related inflation and increased costs at generating facilities.

(18) Reflects 2006 storm costs primarily in the PECO service territory, partially offset by increased storm costs in the ComEd service territory in 2007.

(19) Reflects a one-time benefit approved by the July 2006 ICC rate order to recover previously incurred environmental expenses associated with manufactured gas plants.

(20) Reflects a charitable contribution to the Exelon Foundation.

(21) Reflects the costs associated with the possible construction of a new nuclear plant in Texas.

(22) Reflects decreased planned nuclear refueling outage costs, excluding Salem.

(23) Primarily reflects severance charges in 2007, one-time settlements at PECO and higher NRC fees.

(24) Reflects increased depreciation and amortization primarily due to increased CTC amortization at PECO.

(25) Reflects a reduction of a liability associated with PECO’s property taxes under the PURTA.

(26) Reflects the impact on net income of gains realized in 2007 on AmerGen’s decommissioning trust fund investments related to changes to the investment strategy.

(27) Reflects a favorable income tax benefit associated with Exelon’s method of capitalizing overhead costs.

(28) Primarily reflects the impact on 2006 net income of a research and development tax credit refund and an ITC refund at PECO as well as changes in income tax legislation in Pennsylvania, partially offset by a favorable income tax settlement at ComEd in 2007.

(29) Reflects higher utility revenue taxes at ComEd and PECO and higher interest expense at ComEd, partially offset by lower interest expense at PECO.

(30) Reflects the impact of the 2007 Illinois electric rate settlement.

(31) Reflects the 2007 costs associated with ComEd’s settlement agreement with the City of Chicago.

(32) Reflects the income associated with the termination of Generation’s PPA with State Line.

(33) Reflects the loss associated with Generation’s tolling agreement with Georgia Power related to the contract with Tenaska.

(34) Reflects the gain related to the sale of Generation’s ownership interest in TEG and TEP.

(35) Reflects the settlement of a tax matter at Generation related to Sithe.

(36) Reflects non-cash deferred tax items.

12

EXELON CORPORATION

Reconciliation of Adjusted (non-GAAP) Operating Earnings to

GAAP Consolidated Statements of Operations

(unaudited)

(in millions)

		Generation
	Three Months Ended December 31, 2007							Three Months Ended December 31, 2006
	GAAP (a)		Adjustments			Adjusted Non-GAAP		GAAP (a)		Adjustments			Adjusted Non-GAAP
Operating revenues	$	2,568	$	63	(b),(c)	$	2,631	$	2,074	$	—		$	2,074
Operating expenses
Purchased power		766		(201)	(c),(d),(e)		565		420		38	(d)		458
Fuel		372		41	(d)		413		467		(63)	(d)		404
Operating and maintenance		654		—			654		623		(6)	(d),(j)		617
Depreciation and amortization		67		—			67		70		—			70
Taxes other than income		49		—			49		51		—			51
Total operating expenses		1,908		(160)			1,748		1,631		(31)			1,600
Operating income		660		223			883		443		31			474
Other income and deductions
Interest expense, net		(62)		4	(f)		(58)		(39)		—			(39)
Other, net		87		—			87		11		4	(d),(k)		15
Total other income and deductions		25		4			29		(28)		4			(24)
Income before income taxes		685		227			912		415		35			450
Income taxes		341		51	(b),(c),(d),(e),(f)		392		170		16	(d),(j),(k)		186
Income from continuing operations		344		176			520		245		19			264
Loss from discontinued operations		(1)		—			(1)		—		—			—
Net income	$	343	$	176		$	519	$	245	$	19		$	264
	Twelve Months Ended December 31, 2007							Twelve Months Ended December 31, 2006
	GAAP (a)		Adjustments			Adjusted Non-GAAP		GAAP (a)		Adjustments			Adjusted Non-GAAP
Operating revenues	$	10,749	$	185	(b),(c)	$	10,934	$	9,143	$	—		$	9,143
Operating expenses
Purchased power		2,705		(378)	(c),(d),(e)		2,327		2,027		179	(d)		2,206
Fuel		1,746		81	(d)		1,827		1,951		(77)	(d)		1,874
Operating and maintenance		2,454		29	(g)		2,483		2,305		121	(d),(g),(j),(l)		2,426
Depreciation and amortization		267		—			267		279		—			279
Taxes other than income		185		—			185		185		—			185
Total operating expenses		7,357		(268)			7,089		6,747		223			6,970
Operating income		3,392		453			3,845		2,396		(223)			2,173
Other income and deductions
Interest expense, net		(161)		4	(f)		(157)		(159)		7	(i)		(152)
Equity in earnings (losses) of investments		1		—			1		(9)		—			(9)
Other, net		155		(18)	(h)		137		41		9	(d),(k),(l)		50
Total other income and deductions		(5)		(14)			(19)		(127)		16			(111)
Income before income taxes		3,387		439			3,826		2,269		(207)			2,062
Income taxes		1,362		132	(b),(c),(d),(e),(f),(g),(h)		1,494		866		(79)	(d),(g),(i),(j),(k),(l)		787
Income from continuing operations		2,025		307			2,332		1,403		(128)			1,275
Income (loss) from discontinued operations		4		(5)	(i)		(1)		4		(4)	(i)		—
Net income	$	2,029	$	302		$	2,331	$	1,407	$	(132)		$	1,275

(a) Results reported in accordance with GAAP.

(b) Adjustment to exclude the impact of the 2007 Illinois electric rate settlement.

(c) Adjustment to exclude the income associated with the termination of Generation’s PPA with State Line.

(d) Adjustment to exclude the mark-to-market impact of Generation’s economic hedging activities.

(e) Adjustment to exclude the loss associated with Generation’s tolling agreement with Georgia Power related to the contract with Tenaska.

(f) Adjustment to exclude a non-cash deferred tax item.

(g) Adjustment to exclude the decrease in Generation’s nuclear decommissioning obligation liability primarily related to the AmerGen nuclear plants.

(h) Reflects the increase in the gain related to the first quarter 2007 sale of Generation’s ownership interest in TEG and TEP.

(i) Adjustment to exclude the settlement of separate tax matters at Generation related to Sithe in 2006 and 2007.

(j) Adjustment to exclude severance charges in 2006.

(k) Reflects an impairment charge related to Generation’s investments in TEG and TEP, the sale of which occurred in February 2007.

(l) Adjustment to exclude certain costs associated with Exelon’s merger with PSEG, which was terminated in September 2006.

13

EXELON CORPORATION

Reconciliation of Adjusted (non-GAAP) Operating Earnings to

GAAP Consolidated Statements of Operations

(unaudited)

(in millions)

	ComEd
	Three Months Ended December 31, 2007									Three Months Ended December 31, 2006
	GAAP (a)			Adjustments			Adjusted Non-GAAP			GAAP (a)			Adjustments			Adjusted Non-GAAP
Operating revenues	$	1,436		$	29	(b),(c),(d)	$	1,465		$	1,381		$	—		$	1,381
Operating expenses
Purchased power		841			—			841			669			—			669
Operating and maintenance		313			—			313			101			158	(e)		259
Depreciation and amortization		114			—			114			110			—			110
Taxes other than income		71			—			71			69			—			69
Total operating expenses		1,339			—			1,339			949			158			1,107
Operating income		97			29			126			432			(158	)		274
Other income and deductions
Interest expense, net		(58	)		—			(58	)		(78	)		—			(78	)
Equity in losses of unconsolidated affiliates		(2	)		—			(2	)		(2	)		—			(2	)
Other, net		48			—			48			6			—			6
Total other income and deductions		(12	)		—			(12	)		(74	)		—			(74	)
Income before income taxes		85			29			114			358			(158	)		200
Income taxes		18			12	(b),(c),(d)		30			145			(63	) (e)		82
Net income	$	67		$	17		$	84		$	213		$	(95	)	$	118
	Twelve Months Ended December 31, 2007									Twelve Months Ended December 31, 2006
	GAAP (a)			Adjustments			Adjusted Non-GAAP			GAAP (a)			Adjustments			Adjusted Non-GAAP
Operating revenues	$	6,104		$	51	(b),(c),(d)	$	6,155		$	6,101		$	5	(c)	$	6,106
Operating expenses
Purchased power		3,747			—			3,747			3,292			—			3,292
Operating and maintenance		1,091			(8	) (b)		1,083			745			145	(e),(f),(g)		890
Impairment of goodwill		—			—			—			776			(776	) (h)		—
Depreciation and amortization		440			—			440			430			—			430
Taxes other than income		314			—			314			303			—			303
Total operating expenses		5,592			(8	)		5,584			5,546			(631	)		4,915
Operating income		512			59			571			555			636			1,191
Other income and deductions
Interest expense, net		(318	)		—			(318	)		(308	)		—			(308	)
Equity in losses of unconsolidated affiliates		(7	)		—			(7	)		(10	)		—			(10	)
Other, net		58			—			58			96			(87	) (i)		9
Total other income and deductions		(267	)		—			(267	)		(222	)		(87	)		(309	)
Income before income taxes		245			59			304			333			549			882
Income taxes		80			24	(b),(c),(d)		104			445			(91	) (c),(e),(f),(g),(i)		354
Net income (loss)	$	165		$	35		$	200		$	(112	)	$	640		$	528

(a) Results reported in accordance with GAAP.

(b) Adjustment to exclude the impact of the 2007 Illinois electric rate settlement.

(c) Adjustment to exclude the mark-to-market impact of ComEd’s economic hedging activities.

(d) Adjustment to exclude the 2007 costs associated with ComEd’s settlement agreement with the City of Chicago.

(e) Adjustment to exclude a one-time benefit approved by the December 2006 amended ICC rate order to recover previously incurred severance costs.

(f) Adjustment to exclude certain costs associated with Exelon’s merger with PSEG, which was terminated in September 2006.

(g) Adjustment to exclude severance charges in 2006.

(h) Adjustment to exclude the impairment of ComEd’s goodwill in 2006.

(i) Adjustment to exclude the one-time benefit to recover previously incurred debt costs approved by the July 2006 ICC rate order.

14

EXELON CORPORATION

Reconciliation of Adjusted (non-GAAP) Operating Earnings to

GAAP Consolidated Statements of Operations

(unaudited)

(in millions)

		PECO
	Three Months Ended December 31, 2007								Three Months Ended December 31, 2006
	GAAP (a)			Adjustments		Adjusted Non-GAAP			GAAP (a)			Adjustments			Adjusted Non-GAAP
Operating revenues	$	1,385		$	—	$	1,385		$	1,235		$	—		$	1,235
Operating expenses
Purchased power		571			—		571			493			—			493
Fuel		194			—		194			154			—			154
Operating and maintenance		185			—		185			149			(2	) (b),(c)		147
Depreciation and amortization		182			—		182			162			—			162
Taxes other than income		68			—		68			64			—			64
Total operating expenses		1,200			—		1,200			1,022			(2	)		1,020
Operating income		185			—		185			213			2			215
Other income and deductions
Interest expense, net		(60	)		—		(60	)		(64	)		—			(64	)
Equity in losses of unconsolidated affiliates		(2	)		—		(2	)		(2	)		—			(2	)
Other, net		10			—		10			14			—			14
Total other income and deductions		(52	)		—		(52	)		(52	)		—			(52	)
Income before income taxes		133			—		133			161			2			163
Income taxes		18			—		18			40			1	(b),(c)		41
Net income	$	115		$	—	$	115		$	121		$	1		$	122
	Twelve Months Ended December 31, 2007								Twelve Months Ended December 31, 2006
	GAAP (a)			Adjustments		Adjusted Non-GAAP			GAAP (a)			Adjustments			Adjusted Non-GAAP
Operating revenues	$	5,613		$	—	$	5,613		$	5,168		$	—		$	5,168
Operating expenses
Purchased power		2,366			—		2,366			2,104			—			2,104
Fuel		617			—		617			598						598
Operating and maintenance		630			—		630			628			(13	) (b),(c)		615
Depreciation and amortization		773			—		773			710			(9	) (b)		701
Taxes other than income		280			—		280			262			—			262
Total operating expenses		4,666			—		4,666			4,302			(22	)		4,280
Operating income		947			—		947			866			22			888
Other income and deductions
Interest expense, net		(248	)		—		(248	)		(266	)		—			(266	)
Equity in losses of unconsolidated affiliates		(7	)		—		(7	)		(9	)		—			(9	)
Other, net		45			—		45			30			—			30
Total other income and deductions		(210	)		—		(210	)		(245	)		—			(245	)
Income before income taxes		737			—		737			621			22			643
Income taxes		230			—		230			180			8	(b),(c)		188
Net income	$	507		$	—	$	507		$	441		$	14		$	455

(a) Results reported in accordance with GAAP.

(b) Adjustment to exclude certain costs associated with Exelon’s merger with PSEG, which was terminated in September 2006.

(c) Adjustment to exclude severance charges in 2006.

15

EXELON CORPORATION

Reconciliation of Adjusted (non-GAAP) Operating Earnings to

GAAP Consolidated Statements of Operations

(unaudited)

(in millions)

	Other
	Three Months Ended December 31, 2007									Three Months Ended December 31, 2006
	GAAP (a)			Adjustments			Adjusted Non-GAAP			GAAP (a)			Adjustments			Adjusted Non-GAAP
Operating revenues	$	(835	)	$	—		$	(835	)	$	(994	)	$	—		$	(994	)
Operating expenses
Purchased power		(827	)		(4	) (b)		(831	)		(991	)		—			(991	)
Fuel		(2	)		—			(2	)		—			—			—
Operating and maintenance		23			12	(c)		35			6			(16	) (c),(f)		(10	)
Depreciation and amortization		11			—			11			10			—			10
Taxes other than income		6			—			6			6			—			6
Total operating expenses		(789	)		8			(781	)		(969	)		(16	)		(985	)
Operating loss		(46	)		(8	)		(54	)		(25	)		16			(9	)
Other income and deductions
Interest expense, net		(33	)		—			(33	)		(36	)		2	(c)		(34	)
Equity in losses of unconsolidated affiliates and investments		(13	)		12	(c)		(1	)		(33	)		33	(c)		—
Other, net		91			(75	) (c)		16			30			(25	) (c)		5
Total other income and deductions		45			(63	)		(18	)		(39	)		10			(29	)
Loss from continuing operations before income taxes		(1	)		(71	)		(72	)		(64	)		26			(38	)
Income taxes		(37	)		7	(b),(c),(d)		(30	)		(78	)		56	(c),(f)		(22	)
Income (loss) from continuing operations		36			(78	)		(42	)		14			(30	)		(16	)
Income (loss) from discontinued operations		1			—			1			(1	)		—			(1	)
Net income (loss)	$	37		$	(78	)	$	(41	)	$	13		$	(30	)	$	(17	)
	Twelve Months Ended December 31, 2007									Twelve Months Ended December 31, 2006
	GAAP (a)			Adjustments			Adjusted Non-GAAP			GAAP (a)			Adjustments			Adjusted Non-GAAP
Operating revenues	$	(3,550	)	$	—		$	(3,550	)	$	(4,757	)	$	—		$	(4,757	)
Operating expenses
Purchased power		(3,536	)		—			(3,536	)		(4,740	)		—			(4,740	)
Fuel		(3	)		—			(3	)		—			—			—
Operating and maintenance		114			(93	) (c)		21			190			(230	) (c),(e),(f)		(40	)
Depreciation and amortization		40			—			40			68			(28	) (c)		40
Taxes other than income		18			—			18			21			—			21
Total operating expenses		(3,367	)		(93	)		(3,460	)		(4,461	)		(258	)		(4,719	)
Operating loss		(183	)		93			(90	)		(296	)		258			(38	)
Other income and deductions
Interest expense, net		(123	)		3	(c)		(120	)		(147	)		9	(c)		(138	)
Equity in losses of unconsolidated affiliates and investments		(93	)		93	(c)		—			(83	)		83	(c)		—
Other, net		202			(178	) (c)		24			99			(73	) (c)		26
Total other income and deductions		(14	)		(82	)		(96	)		(131	)		19			(112	)
Loss from continuing operations before income taxes		(197	)		11			(186	)		(427	)		277			(150	)
Income taxes		(226	)		161	(c),(d)		(65	)		(285	)		216	(c),(e),(f)		(69	)
Income (loss) from continuing operations		29			(150	)		(121	)		(142	)		61			(81	)
Income (loss) from discontinued operations		6			—			6			(2	)		—			(2	)
Net income (loss)	$	35		$	(150	)	$	(115	)	$	(144	)	$	61		$	(83	)

(a) Results reported in accordance with GAAP.

(b) Adjustment to exclude the the mark-to-market impact of Exelon’s economic hedging activities.

(c) Adjustment to exclude the financial impact of Exelon’s investments in synthetic fuel-producing facilities, including the impact of mark-to-market gains (losses) associated with the related derivatives.

(d) Adjustment to exclude a non-cash deferred tax item.

(e) Adjustment to exclude certain costs associated with Exelon’s merger with PSEG, which was terminated in September 2006.

(f) Adjustment to exclude severance charges in 2006.

16

EXELON CORPORATION

Exelon Generation Statistics

	Three Months Ended
	December 31, 2007		September 30, 2007		June 30, 2007		March 31, 2007		December 31, 2006
Supply (in GWhs)
Nuclear		34,296		36,356		34,350		35,357		34,810
Purchased Power - Generation		9,068		11,689		8,579		8,683		9,085
Fossil and Hydro		2,350		3,067		2,859		2,994		2,860
Power Team Supply		45,714		51,112		45,788		47,034		46,755
	Three Months Ended
	December 31, 2007		September 30, 2007		June 30, 2007		March 31, 2007		December 31, 2006
Electric Sales (in GWhs)
ComEd		5,362		6,628		5,146		5,926		18,173
PECO		9,957		11,374		9,732		10,279		9,383
Market and Retail		30,395		33,110		30,910		30,829		19,199
Total Electric Sales (a) (b)		45,714		51,112		45,788		47,034		46,755
Average Margin ($/MWh)
Average Realized Revenue
ComEd	$	63.22	$	64.57	$	64.13	$	64.12	$	30.26
PECO		49.31		51.96		51.07		46.70		45.29
Market and Retail		54.81		56.00		54.38		53.07		47.76
Total Electric Sales		54.60		56.21		54.77		53.07		40.47
Average Purchased Power and Fuel Cost (c) (d)	$	18.90	$	23.61	$	18.80	$	16.46	$	15.66
Average Margin (d)	$	35.70	$	32.60	$	35.97	$	36.61	$	24.81
Around-the-clock Market Prices ($/MWh) (e)
PJM West Hub	$	58.68	$	63.34	$	57.61	$	59.82	$	41.66
NiHub		45.92		47.02		44.39		44.80		37.77

(a) Excludes retail gas sales, trading portfolio and other operating revenue.

(b) Total sales do not include trading volume of 4,780 GWhs, 5,667 GWhs, 4,775 GWhs, 5,101 GWhs and 8,029 GWhs for the three months ended December 31, 2007, September 30, 2007, June 30, 2007, March 31, 2007 and December 31, 2006, respectively.

(c) Excludes the net impact of the $119 million pre-tax loss associated with Generation’s tolling agreement with Georgia Power related to the contract with Tenaska and costs associated with the termination of the State Line PPA during the three months ended December 31, 2007.

(d) Excludes the mark-to-market impact of Generation’s economic hedging activities.

(e) Represents the average for the quarter.

17

EXELON CORPORATION

Exelon Generation Statistics

Twelve Months Ended December 31, 2007 and 2006

	December 31, 2007		December 31, 2006
Supply (in GWhs)
Nuclear		140,359		139,610
Purchased Power - Generation		38,021		38,297
Fossil and Hydro		11,270		12,773
Power Team Supply		189,650		190,680
	December 31, 2007		December 31, 2006
Electric Sales (in GWhs)
ComEd		23,062		79,733
PECO		41,343		39,621
Market and Retail Sales		125,245		71,326
Total Electric Sales (a) (b)		189,650		190,680
Average Margin ($/MWh)
Average Realized Revenue
ComEd	$	64.04	$	35.89
PECO		49.80		45.73
Market (c)		54.59		51.03
Total Electric Sales		54.70		43.60
Average Purchased Power and Fuel Cost (d) (e)	$	19.54	$	18.54
Average Margin (e)	$	35.16	$	25.06
Around-the-clock Market Prices ($/MWh) (f)
PJM West Hub	$	59.87	$	51.07
NiHub		45.53		41.42

(a) Excludes retail gas sales, trading portfolio and other operating revenue.

(b) Total sales do not include trading volume of 20,323 GWhs and 31,692 GWhs for the twelve months ended December 31, 2007 and 2006, respectively.

(c) Represents wholesale and retail sales that exclude revenues related to tolling agreements of $86 million for the twelve months ended December 31, 2006.

(d) Excludes the net impact of the $119 million pre-tax loss associated with Generation’s tolling agreement with Georgia Power related to the contract with Tenaska and costs associated with the termination of the State Line PPA during the twelve months ended December 31, 2007.

(e) Excludes the mark-to-market impact of Generation’s economic hedging activities.

(f) Represents the average for the year.

18

EXELON CORPORATION

ComEd Sales Statistics

Three Months Ended December 31, 2007 and 2006

	Electric Deliveries (in GWhs)						Revenue (in millions)
	2007		2006		% Change		2007			2006			% Change
Full Service (a)
Residential	6,929		6,753		2.6	%	$	752		$	554		35.7	%
Small Commercial & Industrial	3,694		6,177		(40.2	%)		365			459		(20.5	%)
Large Commercial & Industrial	319		2,695		(88.2	%)		26			143		(81.8	%)
Public Authorities	203		562		(63.9	%)		17			33		(48.5	%)
Total Full Service	11,145		16,187		(31.1	%)		1,160			1,189		(2.4	%)
PPO (b)
Small Commercial & Industrial	—		8		(100.0	%)		—			1		(100.0	%)
Large Commercial & Industrial	—		6		(100.0	%)		—			—		n.m.
	—		14		(100.0	%)		—			1		(100.0	%)
Delivery Only (c)
Residential	(d	)	(d	)				(d	)		(d	)
Small Commercial & Industrial	4,568		1,572		190.6	%		69			24		187.5	%
Large Commercial & Industrial	6,607		4,006		64.9	%		67			41		63.4	%
Public Authorities & Electric Railroads	124		—		n.m.			1			—		n.m.
	11,299		5,578		102.6	%		137			65		110.8	%
Total PPO and Delivery Only	11,299		5,592		102.1	%		137			66		107.6	%
Total Retail	22,444		21,779		3.1	%		1,297			1,255		3.3	%
Other Revenue (e)								139			126		10.3	%
Total Revenues							$	1,436		$	1,381		4.0	%
Purchased Power							$	841		$	669		25.7	%

Heating and Cooling Degree-Days	2007	2006	Normal
Heating Degree-Days	2,143	2,116	2,311
Cooling Degree-Days	56	9	10

(a) Full service reflects deliveries to customers taking electric service under tariff rates which include the cost of electricity and the cost of the transmission and distribution of the electricity.

(b) Revenue from customers choosing ComEd’s power purchase option includes an energy charge at market rates, transmission and distribution charges and a CTC through December 31, 2006.

(c) Delivery only service reflects customers electing to receive electricity from a competitive electric generation supplier. Revenue from customers choosing a competitive electric generation supplier includes a distribution charge and a CTC through December 31, 2006.

(d) All ComEd customers have the choice to purchase electricity from a competitive electric generation supplier. This choice does not impact the volume of deliveries, but affects revenue collected from customers related to supplied electricity and generation service. As of December 31, 2007, three competitive electric generation suppliers had been granted approval to serve residential customers in the ComEd service territory. However, they are not currently supplying electricity to any residential customers.

(e) Other revenue includes transmission revenue from PJM, sales to municipalities, other wholesale energy sales and economic hedge derivative contracts.

n.m. - Not meaningful

19

EXELON CORPORATION

ComEd Sales Statistics

Twelve Months Ended December 31, 2007 and 2006

	Electric Deliveries (in GWhs)						Revenue (in millions)
	2007		2006		% Change		2007			2006			% Change
Full Service (a)
Residential	29,374		28,330		3.7	%	$	3,161		$	2,453		28.9	%
Small Commercial & Industrial	16,452		24,122		(31.8	%)		1,618			1,882		(14.0	%)
Large Commercial & Industrial	1,915		10,336		(81.5	%)		151			563		(73.2	%)
Public Authorities	766		2,254		(66.0	%)		67			137		(51.1	%)
Total Full Service	48,507		65,042		(25.4	%)		4,997			5,035		(0.8	%)
PPO (b)
Small Commercial & Industrial	16		2,475		(99.4	%)		1			178		(99.4	%)
Large Commercial & Industrial	34		2,259		(98.5	%)		3			137		(97.8	%)
	50		4,734		(98.9	%)		4			315		(98.7	%)
Delivery Only (c)
Residential	(d	)	(d	)				(d	)		(d	)
Small Commercial & Industrial	17,380		5,505		215.7	%		261			85		207.1	%
Large Commercial & Industrial	27,122		15,282		77.5	%		276			155		78.1	%
Public Authorities & Electric Railroads	518		—		n.m.			5			—		n.m.
	45,020		20,787		116.6	%		542			240		125.8	%
Total PPO and Delivery Only	45,070		25,521		76.6	%		546			555		(1.6	%)
Total Retail	93,577		90,563		3.3	%		5,543			5,590		(0.8	%)
Other Revenue (e)								561			511		9.8	%
Total Revenues							$	6,104		$	6,101		0.0	%
Purchased Power							$	3,747		$	3,292		13.8	%

Heating and Cooling Degree-Days	2007	2006	Normal
Heating Degree-Days	6,025	5,589	6,498
Cooling Degree-Days	1,111	931	830

(a) Full service reflects deliveries to customers taking electric service under tariff rates which include the cost of electricity and the cost of the transmission and distribution of the electricity.

(b) Revenue from customers choosing ComEd’s power purchase option includes an energy charge at market rates, transmission and distribution charges and a CTC through December 31, 2006.

(c) Delivery only service reflects customers electing to receive electricity from a competitive electric generation supplier. Revenue from customers choosing a competitive electric generation supplier includes a distribution charge and a CTC through December 31, 2006.

(d) All ComEd customers have the choice to purchase electricity from a competitive electric generation supplier. This choice does not impact the volume of deliveries, but affects revenue collected from customers related to supplied electricity and generation service. As of December 31, 2007, three competitive electric generation suppliers had been granted approval to serve residential customers in the ComEd service territory. However, they are not currently supplying electricity to any residential customers.

(e) Other revenue includes transmission revenue from PJM, sales to municipalities, other wholesale energy sales and economic hedge derivative contracts.

n.m. - Not meaningful

20

EXELON CORPORATION

PECO Sales Statistics

Three Months Ended December 31, 2007 and 2006

	Electric and Gas Deliveries				Revenue (in millions)
	2007	2006 (a)	% Change		2007		2006 (a)		% Change
Electric (in GWhs)
Full Service (b)
Residential	3,179	3,092	2.8	%	$	444	$	414	7.2	%
Small Commercial & Industrial	1,969	1,919	2.6	%		238		222	7.2	%
Large Commercial & Industrial	4,077	3,866	5.5	%		343		308	11.4	%
Public Authorities & Electric Railroads	248	218	13.8	%		24		20	20.0	%
Total Full Service	9,473	9,095	4.2	%		1,049		964	8.8	%
Delivery Only (c)
Residential	8	12	(33.3	%)		1		1	0.0	%
Small Commercial & Industrial	124	143	(13.3	%)		6		7	(14.3	%)
Large Commercial & Industrial	5	2	150.0	%		—		—	n.m.
Total Delivery Only	137	157	(12.7	%)		7		8	(12.5	%)
Total Electric Retail	9,610	9,252	3.9	%		1,056		972	8.6	%
Other Revenue (d)						68		53	28.3	%
Total Electric Revenue						1,124		1,025	9.7	%
Gas (in mmcfs)
Retail Sales	17,838	15,415	15.7	%		241		200	20.5	%
Transportation and Other	7,262	6,324	14.8	%		20		10	100.0	%
Total Gas	25,100	21,739	15.5	%		261		210	24.3	%
Total Electric and Gas Revenues					$	1,385	$	1,235	12.1	%
Purchased Power					$	571	$	493	15.8	%
Fuel						194		154	26.0	%
Total Purchased Power and Fuel					$	765	$	647	18.2	%

Heating and Cooling Degree-Days	2007	2006	Normal
Heating Degree-Days	1,529	1,368	1,671
Cooling Degree-Days	110	17	19

(a) Electric deliveries for residential and small commercial and industrial customers include 175 GWhs and 102 GWhs, respectively, related to a change in the estimate for unbilled revenues.

(b) Full service reflects deliveries to customers taking electric service under tariff rates, which include the cost of electricity, the cost of transmission and distribution of the electricity and a CTC.

(c) Delivery only service reflects customers electing to receive electricity from a competitive electric generation supplier. Revenue from customers choosing an competitive electric generation supplier includes a distribution charge and a CTC.

(d) Other revenue includes transmission revenue from PJM, wholesale revenue and other revenues.

n.m. - Not meaningful

21

EXELON CORPORATION

PECO Sales Statistics

Twelve Months Ended December 31, 2007 and 2006

	Electric and Gas Deliveries				Revenue (in millions)
	2007	2006 (a)	% Change		2007		2006 (a)		% Change
Electric (in GWhs)
Full Service (b)
Residential	13,446	12,796	5.1	%	$	1,948	$	1,780	9.4	%
Small Commercial & Industrial	8,288	7,818	6.0	%		1,042		943	10.5	%
Large Commercial & Industrial	16,522	15,898	3.9	%		1,386		1,286	7.8	%
Public Authorities & Electric Railroads	930	906	2.6	%		89		83	7.2	%
Total Full Service	39,186	37,418	4.7	%		4,465		4,092	9.1	%
Delivery Only (c)
Residential	42	61	(31.1	%)		4		5	(20.0	%)
Small Commercial & Industrial	571	671	(14.9	%)		30		36	(16.7	%)
Large Commercial & Industrial	14	35	(60.0	%)		—		1	(100.0	%)
Total Delivery Only	627	767	(18.3	%)		34		42	(19.0	%)
Total Electric Retail	39,813	38,185	4.3	%		4,499		4,134	8.8	%
Other Revenue (d)						276		238	16.0	%
Total Electric Revenue						4,775		4,372	9.2	%
Gas (in mmcfs)
Retail Sales	58,968	50,578	16.6	%		784		770	1.8	%
Transportation and Other	27,632	25,527	8.2	%		54		26	107.7	%
Total Gas	86,600	76,105	13.8	%		838		796	5.3	%
Total Electric and Gas Revenues					$	5,613	$	5,168	8.6	%
Purchased Power					$	2,366	$	2,104	12.5	%
Fuel						617		598	3.2	%
Total Purchased Power and Fuel					$	2,983	$	2,702	10.4	%

Heating and Cooling Degree-Days	2007	2006	Normal
Heating Degree-Days	4,560	3,924	4,759
Cooling Degree-Days	1,513	1,314	1,235

(a) Electric deliveries for residential and small commercial and industrial customers include 175 GWhs and 102 GWhs, respectively, related to a change in the estimate for unbilled revenues in the fourth quarter of 2006.

(b) Full service reflects deliveries to customers taking electric service under tariff rates, which include the cost of electricity, the cost of transmission and distribution of the electricity and a CTC.

(c) Delivery only service reflects customers electing to receive electricity from a competitive electric generation supplier. Revenue from customers choosing an competitive electric generation supplier includes a distribution charge and a CTC.

(d) Other revenue includes transmission revenue from PJM, wholesale revenue and other revenues.

22