8-K

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549

FORM 8-K

CURRENT REPORT
Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

July 31, 2006
Date of Report (Date of earliest event reported)

Commission File	Exact Name of Registrant as Specified in Its Charter; State of Incorporation;	IRS Employer
Number	Address of Principal Executive Offices; and Telephone Number	Identification Number
1-16169	EXELON CORPORATION (a Pennsylvania corporation) 10 South Dearborn Street—37th Floor P.O. Box 805379 Chicago, Illinois 60680-5379 (312) 394-7398	23-2990190
1-1839	COMMONWEALTH EDISON COMPANY (an Illinois corporation) 440 South LaSalle Street Chicago, Illinois 60605-1028 (312) 394-4321	36-0938600
000-16844	PECO ENERGY COMPANY (a Pennsylvania corporation) P.O. Box 8699 2301 Market Street Philadelphia, Pennsylvania 19101-8699 (215) 841-4000	23-0970240
333-85496	EXELON GENERATION COMPANY, LLC (a Pennsylvania limited liability company) 300 Exelon Way Kennett Square, Pennsylvania 19348 (610) 765-6900	23-3064219

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

o Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

o Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

o Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

o Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Section 2 — Financial Information
Item 2.02. Results of Operations and Financial Condition
Section 7 — Regulation FD
Item 7.01. Regulation FD Disclosure

On July 31, 2006, Exelon Corporation (Exelon) announced via press release Exelon’s results for the second quarter ended June 30, 2006. A copy of the press release and related attachments are attached hereto as Exhibit 99.1. Also attached as Exhibits to this Current Report on Form 8-K are the 2007 around-the-clock historical forward prices (Exhibit 99.2) and the ComEd Rate Case final order summary (Exhibit 99.3). This Form 8-K and the attached exhibits are provided under Items 2.02, 7.01 and 9.01 of Form 8-K and are furnished to, but not filed with, the Securities and Exchange Commission (SEC).

* * * * *

This combined Form 8-K is being furnished separately by Exelon, Commonwealth Edison Company (ComEd), PECO Energy Company (PECO) and Exelon Generation Company, LLC (Generation) (Registrants). Information contained herein relating to any individual registrant has been furnished by such registrant on its own behalf. No registrant makes any representation as to information relating to any other registrant.

Except for the historical information contained herein, certain of the matters discussed in this Report are 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 the forward-looking statements made by a registrant include those factors discussed herein, as well as the items discussed in (a) the Registrants’ 2005 Annual Report on Form 10-K—ITEM 1A. Risk Factors, (b) the Registrants’ 2005 Annual Report on Form 10-K—ITEM 8. Financial Statements and Supplementary Data: Exelon—Note 20, ComEd—Note 17, PECO—Note 15 and Generation—Note 17, and (c) other factors discussed in filings with the SEC by the Registrants. Readers are cautioned not to place undue reliance on these forward-looking statements, which apply only as of the date of this Report. None of the Registrants undertakes any obligation to publicly release any revision to its forward-looking statements to reflect events or circumstances after the date of this Report.

Section 9 — Financial Statements and Exhibits
Item 9.01 — Financial Statements and Exhibits

(c) Exhibits

Exhibit No.	Description
99.1	Press release and earnings release attachments
99.2	2007 around-the-clock historical forward prices
99.3	ComEd Rate Case final order summary

SIGNATURES

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

	EXELON CORPORATION
	PECO ENERGY COMPANY
	EXELON GENERATION COMPANY, LLC
	/s/ John F. Young
	John F. Young
	Executive Vice President, Finance and Markets,
	and Chief Financial Officer
	Exelon Corporation
	COMMONWEALTH EDISON COMPANY
	/s/ Robert K. McDonald
	Robert K. McDonald
	Senior Vice President, Chief Financial Officer,
	Treasurer and Chief Risk Officer
	Commonwealth Edison Company
July 31, 2006

EX-99.1

Contact:	Joyce Carson	FOR IMMEDIATE RELEASE
	Exelon Investor Relations
	312-394-3441
	Jennifer Medley
	Exelon Corporate Communications
	312-394-7189

Exelon Announces Strong Second Quarter Results;
Nuclear Fleet Achieves Superior Operating Performance;
ComEd Receives Disappointing Order in Rate Case

CHICAGO (July 31, 2006) — Exelon Corporation’s (Exelon) second quarter 2006 consolidated earnings prepared in accordance with GAAP were $644 million, or $0.95 per diluted share, compared with earnings of $514 million, or $0.76 per diluted share, in the second quarter of 2005.

Exelon’s adjusted (non-GAAP) operating earnings for the second quarter of 2006 were $577 million, or $0.85 per diluted share, compared with $506 million, or $0.75 per diluted share, for the same period in 2005. The 13 percent increase in adjusted (non-GAAP) operating earnings per share was primarily the result of higher margins on wholesale market sales, increased output due to strong nuclear performance at Exelon Generation Company, LLC (Generation) and higher electric revenues associated with certain authorized rate increases at PECO Energy Company (PECO). These positive factors were partially offset by the effects of unfavorable weather conditions in the Commonwealth Edison Company (ComEd) and PECO service territories, increased depreciation and amortization, including the higher competitive transition charge (CTC) amortization scheduled at PECO, and increased operating and maintenance expense.

The Exelon Nuclear-operated plants achieved a 95.5 percent capacity factor for the second quarter of 2006, compared with 95.4 percent for the second quarter of 2005. In June alone, the Exelon fleet achieved a capacity factor of 99.1 percent, its highest ever for the June-August summer period. Year to date, Nuclear completed five refueling outages, continuing to lead the industry with a 23-day average duration per outage.

“We had a solid first half. Our strong performance in the second quarter more than offset a lackluster first quarter,” said John W. Rowe, Exelon’s chairman, president and CEO. “Our second quarter operating performance was first rate as shown by both a consistently high nuclear capacity factor and the availability of our fossil fleet. Generation margins continued to improve over last year, as did core growth in our delivery service business.” Rowe continued, “Our agreement with DOJ last month was a major milestone in our efforts to complete our proposed merger with PSEG. We are working hard to obtain our last remaining regulatory approval from the New Jersey Board of Public Utilities. We are

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hopeful that we can reach a resolution in New Jersey soon and must do so if we are to be able to complete this transaction.”

A non-GAAP financial measure, adjusted (non-GAAP) operating earnings for the second quarter of 2006 do not include the following items that are included in reported GAAP earnings (all after tax):

• Income of $89 million, or $0.13 per diluted share, resulting from decreases in decommissioning obligations primarily related to the AmerGen nuclear plants.

• A net charge of $55 million, or $0.08 per diluted share, for an impairment related to the write-off of the intangible asset associated with investments in synthetic fuel-producing facilities, net of earnings from the investments, including the impact of mark-to-market gains associated with the related derivatives.

• Mark-to-market gains of $38 million, or $0.06 per diluted share, primarily from Generation’s non-trading activities.

• A net charge of $5 million, or $0.01 per diluted share, related to certain integration costs associated with the proposed merger with Public Service Enterprise Group Incorporated (PSEG) and Generation’s prior investment in Sithe Energies, Inc. (Sithe), which is reflected as discontinued operations.

Adjusted (non-GAAP) operating earnings for the second quarter of 2005 did not include the following items that were included in reported GAAP earnings (all after tax):

• Earnings of $29 million, or $0.04 per diluted share, from investments in synthetic fuel-producing facilities, including the impact of mark-to-market gains associated with the related derivatives.

• Mark-to-market losses of $14 million, or $0.02 per diluted share, from non-trading activities.

• Charges of $7 million, or $0.01 per diluted share, related to certain integration costs associated with the proposed merger with PSEG, severance and severance-related costs and Generation’s prior investment in Sithe, which is reflected as discontinued operations.

ComEd Receives Order in First General Rate Case since 1995

On August 31, 2005, ComEd filed a proposal with the Illinois Commerce Commission (ICC) seeking approval of its first general rate case since January 1995. The rate case filing sought to allocate the costs of supplying electricity and to adjust ComEd’s rates for delivering electricity to users in its service area, effective January 2007, in order to reflect ComEd’s rising costs and significant capital investment in its delivery system. ComEd proposed a revenue increase of $317 million. On June 8, 2006, the administrative law judges issued a proposed order, which included a revenue increase of $164 million, plus ComEd’s request for recovery of several items which were previously recorded as expense. On July 26, 2006, the ICC issued its Final Order, which is subject to rehearing and appeal. The Order allows an $8.3 million revenue increase. ComEd believes that the disallowances contained in the Order are inappropriate and intends to vigorously pursue these issues on rehearing and appeal.

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As part of the rate case, ComEd requested recovery of amounts which have previously been recorded as expense. Based on the ICC Order in the rate case, ComEd estimates that during the third quarter it will record regulatory assets and reverse the previously incurred expenses for the following items (all pre-tax): severance ($158 million), losses on the extinguishment of debt as part of ComEd’s 2004 Accelerated Liability Management Plan ($86 million), manufactured gas plant costs ($40 million) and costs associated with ComEd’s procurement case ($7 million). In addition, ComEd may incur an impairment charge associated with its goodwill in the third quarter due to the ICC Order. As of June 30, 2006, Exelon and ComEd have goodwill of approximately $3.5 billion. Under GAAP, goodwill is tested for impairment at least annually or more frequently if events or circumstances indicate that it is “more likely than not” that goodwill might be impaired. ComEd currently performs its annual test in the fourth quarter of each year. However, due to the significant negative impact of the ICC’s Order to the cash flows and value of ComEd, it is required to complete an interim impairment test during the third quarter of this year. The interim test may lead to an impairment of goodwill at both ComEd and Exelon. The size of any potential impairment will not be known until ComEd completes its test in the third quarter, but the impairment could be material and could exceed the regulatory assets expected to be recorded in the third quarter based on the ICC Order.

“ComEd is deeply disappointed with the Illinois Commerce Commission’s delivery rate order. We believe the facts and record supported a much different result and we will certainly appeal the ICC order and seek reconsideration,” said Frank Clark, ComEd’s chairman and CEO. “We must remember that the Illinois Commissioners have shown both foresight and courage in previous decisions relating to ComEd, and ComEd remains committed to working with the Commission to achieve positive solutions to difficult challenges in Illinois in the long run,” Clark added. “The ICC’s order confirms that ComEd will be allowed to recover its energy costs which will be incurred by the company through the upcoming competitive power procurement auction in Illinois,” Clark noted.

2006 Earnings Outlook

“Given first half performance that was roughly in line with our expectations and our increasing confidence that we will hit our targets in the second half, we are reaffirming our 2006 operating earnings guidance range of $3.00 to $3.30 per share,” said Rowe. Earnings guidance is based on the assumption of normal weather for the remainder of the year.

Exelon’s outlook for 2006 adjusted (non-GAAP) operating earnings excludes the earnings impacts of the following:

• mark-to-market adjustments from non-trading activities;

• investments in synthetic fuel-producing facilities;

• certain costs associated with the proposed merger with PSEG;

• significant impairments of intangible assets, including a potential impairment of ComEd’s goodwill in the third quarter;

• significant changes in decommissioning obligation estimates;

• certain amounts to be recovered by ComEd as approved in the July 26, 2006 ICC rate order, specifically, previously incurred severance costs and losses on extinguishments of long-term debt; and

• other unusual items, including any future changes to GAAP.

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In consideration of these factors, and the need to further analyze the impacts of the ICC’s rate order, Exelon is not updating its 2006 GAAP earnings guidance of $3.00 to $3.30 per share until its analyses are complete, which is expected in the third quarter.

Second Quarter Highlights

•	Proposed Merger with PSEG: On May 30, 2006, the Nuclear Regulatory Commission approved the merger and transfer of the nuclear plant operating licenses from PSEG Nuclear to Generation. On June 22, 2006, Exelon and PSEG reached a comprehensive agreement with the Antitrust Division of the United States Department of Justice (DOJ), which resolves all competition issues reviewed by the DOJ in connection with the proposed merger of Exelon and PSEG. Under the terms of the DOJ agreement, Exelon and PSEG will divest fossil-fuel fired electric generating stations with a total capacity of approximately 5,600 megawatts, assuring that the merger will not adversely affect competition. No divestiture of nuclear capacity or nuclear plants is required by DOJ, as the increased fossil divestiture will resolve all competition issues. The fossil plant divestiture required by the settlement with DOJ will satisfy the requirements imposed by the Federal Energy Regulatory Commission (FERC) to divest fossil generation. The virtual nuclear divestiture approved by FERC in June 2005 continues to be a FERC requirement even though it is not required by DOJ. The divestitures will be required when the merger closes.
	The New Jersey Board of Public Utilities (NJBPU) is the only remaining regulatory authority whose approval is required to complete the merger. Settlement discussions are continuing with the NJBPU staff and other parties. Exelon and PSEG recently made an enhanced settlement proposal that includes concessions that are significantly greater than the concessions originally offered. Exelon and PSEG have also indicated that it is essential to reach a settlement promptly. If Exelon and PSEG are able to reach a settlement in New Jersey, the settlement would need to be reviewed by the Administrative Law Judge presiding over the case and would need to be approved by the NJBPU after public comment. Although it is possible that this process could be completed in time to allow the merger to close in the third quarter of 2006, there is currently no established timetable for NJBPU action on the merger. The final decision on whether to proceed with the merger will rest with the boards of both Exelon and PSEG after the terms and conditions of regulatory requirements are known.
•	ComEd Procurement Case: On January 24, 2006, the ICC approved ComEd’s procurement case, authorizing ComEd to procure power after 2006 through a “reverse-auction” competitive bidding process and to recover the costs from retail customers with no markup. The first auction is scheduled to take place beginning September 5, 2006, and a Web site (www.illinois-auction.com) provides bidder and general information about the Illinois auction process. For the initial auction, ComEd’s entire load will be up for bid. In order to mitigate the effects of changes in future prices, the load for residential and commercial customers less than 400 kW will be served utilizing staggered three-year contracts. On June 1, 2006, the Attorney General filed a petition for review with the Illinois Supreme Court related to the ICC’s order in the procurement case. The petition for review includes a request that the Supreme Court stay the ICC’s order. The Supreme Court has not yet acted on the petition.
•	ComEd Residential Rate Stabilization Program: On May 23, 2006, ComEd filed a residential rate stabilization proposal to ease residential customers’ transition after 2006 to cost-based rates from frozen rates, which requires regulatory approval to implement. The proposal would limit

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	the energy procurement costs that ComEd could pass through to its customers for a specified period of time and allow ComEd to collect any unrecovered procurement costs, including appropriate returns, in later years. The plan would terminate if a material adverse event occurs or if ComEd’s senior unsecured credit rating for at least one of the three major credit rating agencies falls below investment grade. ComEd has requested an ICC ruling on the proposal by late November 2006. Hearings on the proposal are scheduled for September 7 and 8. ComEd is reviewing this initiative in light of the ICC order on the delivery rate case.
•	Nuclear Operations: Generation’s nuclear fleet, including its owned output from the Salem Generating Station operated by PSEG and co-owned by Generation, produced 35,442 GWhs in the second quarter of 2006, compared with 34,685 GWhs in the second quarter of 2005. The Exelon Nuclear-operated plants completed two scheduled refueling outages in both of the second quarters of 2006 and 2005, and refueling outage days totaled 35 and 36, respectively. Total non-refueling outage days for the Exelon Nuclear-operated plants in the second quarter of 2006 were 24 versus 26 in the second quarter of 2005.
•	Fossil and Hydro Operations: Generation’s fossil fleet commercial availability was 93.7 percent in the second quarter of 2006, compared with 94.8 percent in the second quarter of 2005, primarily due to unplanned maintenance outages. The equivalent availability factor for the hydro facilities was 95.2 percent, a 2.7 percent improvement over the second quarter 2005 performance, largely due to less planned outage work performed in the second quarter 2006.

BUSINESS UNIT RESULTS

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

ComEd’s net income in the second quarter of 2006 was $127 million compared with net income of $109 million in the second quarter of 2005. The second quarter 2006 net income included (all after tax) mark-to-market gains of $2 million from one wholesale contract and expenses of $1 million related to certain integration costs associated with the proposed merger with PSEG. Second quarter 2005 net income included after-tax income of $2 million related to adjustments to previously recorded severance and severance-related charges. Excluding the impact of these items, ComEd’s net income in the second quarter of 2006 increased $19 million compared with the same quarter last year, primarily due to lower purchased power expense attributable to a contractual decrease in prices associated with ComEd’s power purchase agreement with Generation, core growth in customers and deliveries and favorable changes in customer mix and usage, partially offset by the impact of less favorable weather.

In the ComEd service territory, cooling degree-days were down 32 percent relative to the same period in 2005 and were 2 percent below normal. ComEd’s total retail kWh deliveries decreased 2 percent in 2006 as compared with 2005, with a 2 percent decrease in deliveries to the residential customer class, largely due to less favorable weather. ComEd’s second quarter 2006 revenues were $1,453 million, down 2 percent from $1,488 million in 2005, primarily due to decreased deliveries to residential and Power Purchase Option (PPO) customers. For ComEd, weather had an unfavorable after-tax impact of $20 million on second quarter 2006 earnings relative to 2005 and had an unfavorable after-tax impact of $4 million relative to the normal weather that was incorporated in earnings guidance.

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The number of customers being served in the ComEd region has increased 1.1 percent since the second quarter of 2005, with weather-normalized kWh growth of 1.8 percent compared with the second quarter of 2005.

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

PECO’s net income in the second quarter of 2006 was $93 million compared with net income of $110 million in the second quarter of 2005. The second quarter 2006 net income included after-tax expenses of $3 million related to certain integration costs associated with the proposed merger with PSEG. Second quarter 2005 net income included after-tax charges of $4 million related to certain integration costs associated with the proposed merger with PSEG. Excluding the impact of these items, PECO’s net income in the second quarter of 2006 decreased $18 million compared with the same quarter last year, primarily due to higher CTC amortization and higher operating and maintenance expense, partially offset by higher revenues, net of purchased power and fuel expense. Higher net revenues reflected certain authorized electric rate increases, including a scheduled CTC rate increase, partially offset by lower net electric and gas revenues as a result of unfavorable weather. The increases in CTC amortization expense and CTC rates are in accordance with PECO’s 1998 restructuring settlement with the PAPUC. As expected, the increase in CTC amortization expense exceeded the increase in CTC revenues.

In the PECO service territory, cooling degree-days were the same as in 2005 and were 3 percent above normal, while heating degree days were 31 percent below 2005 and normal. PECO’s total electric retail kWh deliveries increased less than 1 percent, with residential deliveries down 1 percent. Total gas deliveries were down 7 percent from the 2005 period. PECO’s second quarter 2006 revenues were $1,148 million, up 10 percent from $1,044 million in 2005, primarily due to the above-mentioned electric rate increases and a net increase in gas rates through PAPUC-approved changes to the purchased gas adjustment clause. For PECO, weather had an unfavorable after-tax impact of $6 million on second quarter 2006 earnings relative to 2005 and an unfavorable after-tax impact of $6 million relative to the normal weather that was incorporated in earnings guidance.

The number of electric customers being served in the PECO region has increased 0.7 percent since the second quarter of 2005, with weather-normalized kWh growth of 1.2 percent compared with the second quarter of 2005.

Exelon Generation consists of Exelon’s electric generation operations, competitive retail sales and power marketing and trading functions.

Second quarter 2006 net income was $500 million compared with $296 million in the second quarter of 2005. Second quarter 2006 net income included (all after tax) income of $89 million resulting from decreases in decommissioning obligations primarily related to the AmerGen nuclear plants, mark-to-market gains of $36 million from non-trading activities, costs of $2 million related to certain integration costs associated with the proposed merger with PSEG and income of $2 million related to Generation’s prior investment in Sithe, which is reflected as discontinued operations. Second quarter 2005 net income included (all after tax) mark-to-market losses of $14 million from non-trading activities, costs of $1 million related to the proposed merger with PSEG, severance and severance-related costs of $1 million and charges of $1 million related to Generation’s prior investment in Sithe, which is reflected as discontinued operations. Excluding the impact of these items, Generation’s net income in the second quarter of 2006 increased $62 million compared with the same quarter last year, primarily due to higher

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revenue, net of purchased power and fuel expense, partially offset by higher other operating and maintenance expense largely due to inflationary increases.

Generation’s revenue, net of purchased power and fuel expense, increased by $131 million in the second quarter of 2006 compared with the second quarter of 2005 excluding the mark-to-market impact in both years. The quarter-over-quarter increase in revenue, net of purchased power and fuel expense, was driven by higher average margins on wholesale market sales due to having previously re-priced forward hedges at higher prices, combined with higher spot market prices and the impact of higher generation output, as well as the contractual increase in the prices associated with Generation’s power sales agreement with PECO, partially offset by the contractual decrease in prices associated with Generation’s power sales agreement with ComEd. Generation’s average realized margin on all electric sales, including sales to affiliates and excluding trading activity, was $26.43 per MWh in the second quarter of 2006 compared with $23.06 per MWh in the second quarter of 2005.

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 non-trading 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 July 31, 2006.

Conference call information: Exelon has scheduled a conference call for 11 AM ET (10 AM CT) on July 31, 2006. The call-in number in the U.S. is 888-603-6873, and the international call-in number is 973-582-2706. No password is required. 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.)

Telephone replays will be available until August 14. The U.S. call-in number for replays is 877-519-4471, and the international call-in number is 973-341-3080. The confirmation code is 7592439.

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 Corporation’s 2005 Annual Report on Form 10-K in (a) ITEM 1A. Risk Factors and (b) ITEM 8. Financial Statements and Supplementary Data: Exelon-Note 20, ComEd-Note 17, PECO-Note 15 and Generation-Note 17 and (2) 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 5.2 million customers and more than $15 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 5.2 million customers in Illinois and Pennsylvania and natural gas to more than 470,000 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 Income — Three Months Ended June 30, 2006 and 2005	1
Consolidating Statements of Income — Six Months Ended June 30, 2006 and 2005	2
Business Segment Comparative Income Statements — ComEd and PECO — Three and Six Months Ended June 30, 2006 and 2005	3
Business Segment Comparative Income Statements — Generation and Other — Three and Six Months Ended June 30, 2006 and 2005	4
Consolidated Balance Sheets — June 30, 2006 and December 31, 2005	5
Consolidated Statements of Cash Flows — Six Months Ended June 30, 2006 and 2005	6
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Consolidated Statements of Income — Exelon — Three Months Ended June 30, 2006 and 2005	7
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Consolidated Statements of Income — Exelon — Six Months Ended June 30, 2006 and 2005	8
Reconciliation of Adjusted (non-GAAP) Operating Earnings Per Diluted Share to GAAP Earnings Per Diluted Share — Three Months Ended June 30, 2006 and 2005	9
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Earnings By Business Segment — Three Months Ended June 30, 2006 and 2005	10
Reconciliation of Adjusted (non-GAAP) Operating Earnings Per Diluted Share to GAAP Earnings Per Diluted Share — Six Months Ended June 30, 2006 and 2005	11
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Earnings By Business Segment — Six Months Ended June 30, 2006 and 2005	12
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Consolidated Statements of Income — ComEd — Three and Six Months Ended June 30, 2006 and 2005	13
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Consolidated Statements of Income — PECO — Three and Six Months Ended June 30, 2006 and 2005	14
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Consolidated Statements of Income — Generation — Three and Six Months Ended June 30, 2006 and 2005	15
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Consolidated Statements of Income — Other — Three and Six Months Ended June 30, 2006 and 2005	16
Electric Sales Statistics — Three and Six Months Ended June 30, 2006 and 2005	17
ComEd and PECO Sales Statistics — Three Months Ended June 30, 2006 and 2005	18
ComEd and PECO Sales Statistics — Six Months Ended June 30, 2006 and 2005	19
Exelon Generation Power Marketing Statistics — Three Months Ended June 30, 2006, March, 31, 2006, December 31, 2005, September 30, 2005 and June 30, 2005	20
Exelon Generation Power Marketing Statistics — Six Months Ended June 30, 2006 and 2005	21

EXELON CORPORATION
Consolidating Statements of Income
(unaudited)
(in millions)

	Three Months Ended June 30, 2006
													Exelon
	ComEd			PECO			Generation			Other			Consolidated
Operating revenues	$	1,453		$	1,148		$	2,214		$	(1,118	)	$	3,697
Operating expenses
Purchased power		766			501			418			(1,114	)		571
Fuel		—			76			425			1			502
Operating and maintenance		218			141			440			82			881
Depreciation and amortization		106			172			72			21			371
Taxes other than income		71			53			41			5			170
Total operating expenses		1,161			943			1,396			(1,005	)		2,495
Operating income (loss)		292			205			818			(113	)		1,202
Other income and deductions
Interest expense		(77	)		(67	)		(40	)		(38	)		(222	)
Equity in losses of unconsolidated affiliates		(3	)		(2	)		(1	)		(16	)		(22	)
Other, net		1			2			14			29			46
Total other income and deductions		(79	)		(67	)		(27	)		(25	)		(198	)
Income (loss) from continuing operations before income taxes		213			138			791			(138	)		1,004
Income taxes		86			45			294			(62	)		363
Income (loss) from continuing operations		127			93			497			(76	)		641
Income from discontinued operations		—			—			3			—			3
Net income (loss)	$	127		$	93		$	500		$	(76	)	$	644

	Three Months Ended June 30, 2005
													Exelon
	ComEd			PECO			Generation			Other			Consolidated
Operating revenues	$	1,488		$	1,044		$	2,105		$	(1,153	)	$	3,484
Operating expenses
Purchased power		858			437			517			(1,149	)		663
Fuel		—			66			428			(1	)		493
Operating and maintenance		202			119			602			6			929
Depreciation and amortization		101			137			63			24			325
Taxes other than income		73			60			39			5			177
Total operating expenses		1,234			819			1,649			(1,115	)		2,587
Operating income (loss)		254			225			456			(38	)		897
Other income and deductions
Interest expense		(77	)		(70	)		(29	)		(34	)		(210	)
Equity in earnings (losses) of unconsolidated affiliates		(4	)		(4	)		4			(28	)		(32	)
Other, net		7			6			51			4			68
Total other income and deductions		(74	)		(68	)		26			(58	)		(174	)
Income (loss) from continuing operations before income taxes		180			157			482			(96	)		723
Income taxes		71			47			185			(96	)		207
Income from continuing operations		109			110			297			—			516
Loss from discontinued operations		—			—			(1	)		(1	)		(2	)
Net income (loss)	$	109		$	110		$	296		$	(1	)	$	514

1

EXELON CORPORATION
Consolidating Statements of Income
(unaudited)
(in millions)

	Six Months Ended June 30, 2006
													Exelon
	ComEd			PECO			Generation			Other			Consolidated
Operating revenues	$	2,880		$	2,554		$	4,434		$	(2,309	)	$	7,559
Operating expenses
Purchased power		1,628			987			781			(2,300	)		1,096
Fuel		—			402			1,036			—			1,438
Operating and maintenance		434			289			1,108			75			1,906
Depreciation and amortization		205			343			139			48			735
Taxes other than income		152			117			84			11			364
Total operating expenses		2,419			2,138			3,148			(2,166	)		5,539
Operating income (loss)		461			416			1,286			(143	)		2,020
Other income and deductions
Interest expense		(153	)		(136	)		(82	)		(74	)		(445	)
Equity in losses of unconsolidated affiliates		(5	)		(6	)		(5	)		(45	)		(61	)
Other, net		1			5			20			65			91
Total other income and deductions		(157	)		(137	)		(67	)		(54	)		(415	)
Income (loss) from continuing operations before income taxes		304			279			1,219			(197	)		1,605
Income taxes		123			93			454			(106	)		564
Income (loss) from continuing operations		181			186			765			(91	)		1,041
Income from discontinued operations		—			—			3			—			3
Net income (loss)	$	181		$	186		$	768		$	(91	)	$	1,044

	Six Months Ended June 30, 2005
													Exelon
	ComEd			PECO			Generation			Other			Consolidated
Operating revenues	$	2,875		$	2,339		$	4,125		$	(2,294	)	$	7,045
Operating expenses
Purchased power		1,679			869			967			(2,283	)		1,232
Fuel		—			331			786			(2	)		1,115
Operating and maintenance		404			253			1,211			9			1,877
Depreciation and amortization		198			273			125			48			644
Taxes other than income		151			115			74			9			349
Total operating expenses		2,432			1,841			3,163			(2,219	)		5,217
Operating income (loss)		443			498			962			(75	)		1,828
Other income and deductions
Interest expense		(151	)		(142	)		(58	)		(48	)		(399	)
Equity in earnings (losses) of unconsolidated affiliates		(8	)		(8	)		4			(56	)		(68	)
Other, net		13			9			69			6			97
Total other income and deductions		(146	)		(141	)		15			(98	)		(370	)
Income (loss) from continuing operations before income taxes		297			357			977			(173	)		1,458
Income taxes		118			118			376			(177	)		435
Income from continuing operations		179			239			601			4			1,023
Income (loss) from discontinued operations		—			—			15			(3	)		12
Net income	$	179		$	239		$	616		$	1		$	1,035

2

EXELON CORPORATION
Business Segment Comparative Income Statements
(unaudited)
(in millions)

	ComEd
	Three Months Ended June 30,									Six Months Ended June 30,
	2006			2005			Variance			2006			2005			Variance
Operating revenues	$	1,453		$	1,488		$	(35	)	$	2,880		$	2,875		$	5
Operating expenses
Purchased power		766			858			(92	)		1,628			1,679			(51	)
Operating and maintenance		218			202			16			434			404			30
Depreciation and amortization		106			101			5			205			198			7
Taxes other than income		71			73			(2	)		152			151			1
Total operating expenses		1,161			1,234			(73	)		2,419			2,432			(13	)
Operating income		292			254			38			461			443			18
Other income and deductions
Interest expense		(77	)		(77	)		—			(153	)		(151	)		(2	)
Equity in losses of unconsolidated affiliates		(3	)		(4	)		1			(5	)		(8	)		3
Other, net		1			7			(6	)		1			13			(12	)
Total other income and deductions		(79	)		(74	)		(5	)		(157	)		(146	)		(11	)
Income before income taxes		213			180			33			304			297			7
Income taxes		86			71			15			123			118			5
Net income	$	127		$	109		$	18		$	181		$	179		$	2

	PECO
	Three Months Ended June 30,									Six Months Ended June 30,
	2006			2005			Variance			2006			2005			Variance
Operating revenues	$	1,148		$	1,044		$	104		$	2,554		$	2,339		$	215
Operating expenses
Purchased power		501			437			64			987			869			118
Fuel		76			66			10			402			331			71
Operating and maintenance		141			119			22			289			253			36
Depreciation and amortization		172			137			35			343			273			70
Taxes other than income		53			60			(7	)		117			115			2
Total operating expenses		943			819			124			2,138			1,841			297
Operating income		205			225			(20	)		416			498			(82	)
Other income and deductions
Interest expense		(67	)		(70	)		3			(136	)		(142	)		6
Equity in losses of unconsolidated affiliates		(2	)		(4	)		2			(6	)		(8	)		2
Other, net		2			6			(4	)		5			9			(4	)
Total other income and deductions		(67	)		(68	)		1			(137	)		(141	)		4
Income before income taxes		138			157			(19	)		279			357			(78	)
Income taxes		45			47			(2	)		93			118			(25	)
Net income	$	93		$	110		$	(17	)	$	186		$	239		$	(53	)

3

EXELON CORPORATION
Business Segment Comparative Income Statements
(unaudited)
(in millions)

	Generation
	Three Months Ended June 30,									Six Months Ended June 30,
	2006			2005			Variance			2006			2005			Variance
Operating revenues	$	2,214		$	2,105		$	109		$	4,434		$	4,125		$	309
Operating expenses
Purchased power		418			517			(99	)		781			967			(186	)
Fuel		425			428			(3	)		1,036			786			250
Operating and maintenance		440			602			(162	)		1,108			1,211			(103	)
Depreciation and amortization		72			63			9			139			125			14
Taxes other than income		41			39			2			84			74			10
Total operating expenses		1,396			1,649			(253	)		3,148			3,163			(15	)
Operating income		818			456			362			1,286			962			324
Other income and deductions
Interest expense		(40	)		(29	)		(11	)		(82	)		(58	)		(24	)
Equity in earnings (losses) of unconsolidated affiliates		(1	)		4			(5	)		(5	)		4			(9	)
Other, net		14			51			(37	)		20			69			(49	)
Total other income and deductions		(27	)		26			(53	)		(67	)		15			(82	)
Income from continuing operations before income taxes		791			482			309			1,219			977			242
Income taxes		294			185			109			454			376			78
Income from continuing operations		497			297			200			765			601			164
Income (loss) from discontinued operations		3			(1	)		4			3			15			(12	)
Net income	$	500		$	296		$	204		$	768		$	616		$	152

	Other (a)
	Three Months Ended June 30,									Six Months Ended June 30,
	2006			2005			Variance			2006			2005			Variance
Operating revenues	$	(1,118	)	$	(1,153	)	$	35		$	(2,309	)	$	(2,294	)	$	(15	)
Operating expenses
Purchased power		(1,114	)		(1,149	)		35			(2,300	)		(2,283	)		(17	)
Fuel		1			(1	)		2			—			(2	)		2
Operating and maintenance		82			6			76			75			9			66
Depreciation and amortization		21			24			(3	)		48			48			—
Taxes other than income		5			5			—			11			9			2
Total operating expenses		(1,005	)		(1,115	)		110			(2,166	)		(2,219	)		53
Operating loss		(113	)		(38	)		(75	)		(143	)		(75	)		(68	)
Other income and deductions
Interest expense		(38	)		(34	)		(4	)		(74	)		(48	)		(26	)
Equity in losses of unconsolidated affiliates		(16	)		(28	)		12			(45	)		(56	)		11
Other, net		29			4			25			65			6			59
Total other income and deductions		(25	)		(58	)		33			(54	)		(98	)		44
Loss from continuing operations before income taxes		(138	)		(96	)		(42	)		(197	)		(173	)		(24	)
Income taxes		(62	)		(96	)		34			(106	)		(177	)		71
Income (loss) from continuing operations		(76	)		—			(76	)		(91	)		4			(95	)
Loss from discontinued operations		—			(1	)		1			—			(3	)		3
Net income (loss)	$	(76	)	$	(1	)	$	(75	)	$	(91	)	$	1		$	(92	)

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

4

EXELON CORPORATION
Consolidated Balance Sheets
(unaudited)
(in millions)

	June 30,			December 31,
	2006			2005
Current assets
Cash and cash equivalents	$	282		$	140
Restricted cash and investments		48			49
Accounts receivable, net Customer		1,609			1,858
Other		265			337
Mark-to-market derivative assets		737			916
Inventories, at average cost
Fossil fuel		282			311
Materials and supplies		381			351
Deferred income taxes		114			80
Other		540			595
Total current assets		4,258			4,637
Property, plant and equipment, net		22,122			21,981
Deferred debits and other assets
Regulatory assets		4,093			4,386
Nuclear decommissioning trust funds		5,809			5,585
Investments		819			813
Goodwill		3,476			3,475
Mark-to-market derivative assets		586			371
Prepaid pension asset		374			377
Other		753			824
Total deferred debits and other assets		15,910			15,831
Total assets	$	42,290		$	42,449
Liabilities and shareholders’ equity
Current liabilities
Commercial paper and notes payable	$	1,184		$	1,290
Long-term debt due within one year		554			407
Long-term debt to ComEd Transitional Funding Trust and PECO Energy Transition Trust due within one year		577			507
Accounts payable		1,195			1,467
Mark-to-market derivative liabilities		885			1,282
Accrued expenses		1,070			1,005
Other		838			605
Total current liabilities		6,303			6,563
Long-term debt		7,904			7,759
Long-term debt to ComEd Transitional Funding Trust and PECO Energy Transition Trust		2,963			3,456
Long-term debt to other financing trusts		545			545
Deferred credits and other liabilities
Deferred income taxes		4,957			4,816
Unamortized investment tax credits		256			262
Asset retirement obligations		3,676			4,157
Pension obligations		292			268
Non-pension postretirement benefits obligations		1,086			1,014
Spent nuclear fuel obligation		926			906
Regulatory liabilities		2,293			2,170
Mark-to-market derivative liabilities		504			522
Other		763			798
Total deferred credits and other liabilities		14,753			14,913
Total liabilities		32,468			33,236
Minority interest of consolidated subsidiaries		—			1
Preferred securities of subsidiaries		87			87
Shareholders’ equity
Common stock		8,166			7,987
Treasury stock, at cost		(497	)		(444	)
Retained earnings		3,443			3,206
Accumulated other comprehensive loss		(1,377	)		(1,624	)
Total shareholders’ equity		9,735			9,125
Total liabilities and shareholders’ equity	$	42,290		$	42,449

5

EXELON CORPORATION
Consolidated Statements of Cash Flows
(in millions)

	Six Months Ended
	June 30,
	2006			2005
Cash flows from operating activities
Net income	$	1,044		$	1,035
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion, including nuclear fuel		1,060			961
Deferred income taxes and amortization of investment tax credits		(81	)		528
Provision for uncollectible accounts		42			22
Equity in losses of unconsolidated affiliates		61			68
Gains on sales of investments and wholly owned subsidiaries		(2	)		(17	)
Net realized (gains) losses on nuclear decommissioning trust funds		11			(55	)
Other decommissioning-related activities		(149	)		13
Impairment charges		117			—
Other non-cash operating activities		32			27
Changes in assets and liabilities:
Accounts receivable		230			53
Inventories		11			26
Other current assets		(136	)		(136	)
Accounts payable, accrued expenses and other current liabilities		(406	)		(211	)
Counterparty collateral asset		178			(20	)
Counterparty collateral liability		5			7
Income taxes		300			24
Net realized and unrealized mark-to-market and hedging transactions		(69	)		(74	)
Pension and non-pension postretirement benefits		99			(1,927	)
Other noncurrent assets and liabilities		(159	)		(38	)
Net cash flows provided by operating activities		2,188			286
Cash flows from investing activities
Capital expenditures		(1,156	)		(1,007	)
Proceeds from nuclear decommissioning trust fund assets sales		2,554			2,149
Investment in nuclear decommissioning trust funds		(2,706	)		(2,256	)
Acquisition of businesses, net of cash acquired		—			(97	)
Proceeds from sales of investments and wholly owned subsidiaries, net of $32 million of cash sold during the six months ended June 30, 2005		1			103
Investment in synthetic fuel-producing facilities		(53	)		(56	)
Change in restricted cash		1			23
Other investing activities		(1	)		(2	)
Net cash flows used in investing activities		(1,360	)		(1,143	)
Cash flows from financing activities
Issuance of long-term debt		326			1,788
Retirement of long-term debt		(34	)		(185	)
Retirement of long-term debt to financing affiliates		(422	)		(397	)
Issuance of short-term debt		—			2,500
Retirement of short-term debt		—			(2,200	)
Change in other short-term debt		(106	)		(161	)
Dividends paid on common stock		(535	)		(535	)
Proceeds from employee stock plans		107			156
Purchase of treasury stock		(53	)		(8	)
Other financing activities		31			(55	)
Net cash flows provided by (used in) financing activities		(686	)		903
Increase in cash and cash equivalents		142			46
Cash and cash equivalents at beginning of period		140			499
Cash and cash equivalents at end of period	$	282		$	545

6

EXELON CORPORATION

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

(unaudited)

(in millions, except per share data)

	Three Months Ended June 30, 2006										Three Months Ended June 30, 2005
								Adjusted										Adjusted
	GAAP (a)			Adjustments				Non-GAAP			GAAP (a)			Adjustments				Non-GAAP
Operating revenues	$	3,697		$	(3	)	(b)	$	3,694		$	3,484		$	—			$	3,484
Operating expenses
Purchased power		571			49		(b)		620			663			15		(b)		678
Fuel		502			9		(b)		511			493			(37	)	(b)		456
Operating and maintenance		881			43		(c),(d),(e)		924			929			(16	)	(c),(d),(g)		913
Depreciation and amortization		371			(14	)	(c),(d)		357			325			(19	)	(c),(d)		306
Taxes other than income		170			—				170			177			—				177
Total operating expenses		2,495			87				2,582			2,587			(57	)			2,530
Operating income		1,202			(90	)			1,112			897			57				954
Other income and deductions
Interest expense		(222	)		4		(c),(f)		(218	)		(210	)		4		(c)		(206	)
Equity in losses of unconsolidated affiliates		(22	)		16		(c)		(6	)		(32	)		28		(c)		(4	)
Other, net		46			(24	)	(c)		22			68			—				68
Total other income and deductions		(198	)		(4	)			(202	)		(174	)		32				(142	)
Income from continuing operations before income taxes		1,004			(94	)			910			723			89				812
Income taxes		363			(30	)	(b),(c),(d),(e),(f)		333			207			98		(b),(c),(d),(g)		305
Income from continuing operations		641			(64	)			577			516			(9	)			507
Income (loss) from discontinued operations		3			(3	)	(f)		—			(2	)		1		(f)		(1	)
Net income	$	644		$	(67	)		$	577		$	514		$	(8	)		$	506
Earnings per average common share
Basic:	$	0.96		$	(0.10	)		$	0.86		$	0.77		$	(0.01	)		$	0.76
Diluted:	$	0.95		$	(0.10	)		$	0.85		$	0.76		$	(0.01	)		$	0.75
Average common shares outstanding
Basic		670							670			670							670
Diluted		676							676			677							677
Effect of adjustments on earnings per average diluted common share recorded in accordance with GAAP:
Mark-to-market (b)				$	0.06									$	(0.02	)
Investments in synthetic fuel-producing facilities (c)					(0.08	)									0.04
PSEG merger costs (d)					(0.01	)									(0.01	)
Nuclear decommissioning obligation reduction (e)					0.13										—
Severance charges and financial impact of Sithe (f),(g)					—										—
Total adjustments				$	0.10									$	0.01

(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 non-trading 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 associated with the related derivatives.
(d)	Adjustment to exclude certain costs associated with Exelon’s anticipated merger with Public Service Enterprise Group, Inc. (PSEG).
(e)	Adjustment to exclude the decrease in Generation’s nuclear decommissioning obligation liability related to the AmerGen nuclear plants.
(f)	Adjustment to exclude the financial impact of Generation’s prior investment in Sithe Energies, Inc. (Sithe) (sold in January 2005).
(g)	Adjustment to exclude severance charges.

7

EXELON CORPORATION

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

(unaudited)

(in millions, except per share data)

	Six Months Ended June 30, 2006										Six Months Ended June 30, 2005
								Adjusted										Adjusted
	GAAP (a)			Adjustments				Non-GAAP			GAAP (a)			Adjustments				Non-GAAP
Operating revenues	$	7,559		$	8		(b)	$	7,567		$	7,045		$	—			$	7,045
Operating expenses
Purchased power		1,096			88		(b)		1,184			1,232			(4	)	(b)		1,228
Fuel		1,438			(52	)	(b)		1,386			1,115			45		(b)		1,160
Operating and maintenance		1,906			33		(c),(d),(e),(f)		1,939			1,877			(33	)	(c),(d),(f)		1,844
Depreciation and amortization		735			(35	)	(c),(d)		700			644			(37	)	(c),(d)		607
Taxes other than income		364			—				364			349			—				349
Total operating expenses		5,539			34				5,573			5,217			(29	)			5,188
Operating income		2,020			(26	)			1,994			1,828			29				1,857
Other income and deductions
Interest expense		(445	)		12		(c),(g)		(433	)		(399	)		8		(c)		(391	)
Equity in losses of unconsolidated affiliates		(61	)		46		(c)		(15	)		(68	)		56		(c)		(12	)
Other, net		91			(49	)	(c),(d)		42			97			—				97
Total other income and deductions		(415	)		9				(406	)		(370	)		64				(306	)
Income from continuing operations before income taxes		1,605			(17	)			1,588			1,458			93				1,551
Income taxes		564			27		(b),(c),(d),(e),(f),(g)		591			435			156		(b),(c),(d),(f)		591
Income from continuing operations		1,041			(44	)			997			1,023			(63	)			960
Income (loss) from discontinued operations		3			(3	)	(g)		—			12			(15	)	(g)		(3	)
Net Income	$	1,044		$	(47	)		$	997		$	1,035		$	(78	)		$	957
Earnings per average common share
Basic:
Income from continuing operations	$	1.56		$	(0.07	)		$	1.49		$	1.53		$	(0.09	)		$	1.44
Income (loss) from discontinued operations		—			—				—			0.02			(0.02	)			—
Net income	$	1.56		$	(0.07	)		$	1.49		$	1.55		$	(0.11	)		$	1.44
Diluted:
Income from continuing operations	$	1.55		$	(0.07	)		$	1.48		$	1.51		$	(0.09	)		$	1.42
Income (loss) from discontinued operations		—			—				—			0.02			(0.02	)			—
Net income	$	1.55		$	(0.07	)		$	1.48		$	1.53		$	(0.11	)		$	1.42
Average common shares outstanding
Basic		669							669			669							669
Diluted		675							675			676							676
Effect of adjustments on earnings per average diluted common share recorded in accordance with GAAP:
Mark-to-market (b)				$	0.03									$	0.03
Investments in synthetic fuel-producing facilities (c)					(0.06	)									0.07
PSEG merger costs (d)					(0.02	)									(0.01	)
Nuclear decommissioning obligation reduction (e)					0.13										—
Severance charges and financial impact of Sithe (f),(g)					(0.01	)									0.02
Total adjustments				$	0.07									$	0.11

(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 non-trading 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 associated with the related derivatives.
(d)	Adjustment to exclude certain costs associated with Exelon’s anticipated merger with PSEG.
(e)	Adjustment to exclude the decrease in Generation’s nuclear decommissioning obligation liability related to the AmerGen nuclear plants.
(f)	Adjustment to exclude severance charges.
(g)	Adjustment to exclude the financial impact of Generation’s prior investment in Sithe (sold in January 2005).

8

EXELON CORPORATION

Reconciliation of Adjusted (non-GAAP) Operating Earnings
Per Diluted Share to GAAP Earnings Per Diluted Share

Three Months Ended June 30, 2006 and 2005

2005 GAAP Earnings per Diluted Share	$	0.76
2005 Adjusted (non-GAAP) Operating Earnings Adjustments:
Mark-to-Market (1)		0.02
Investments in Synthetic Fuel-Producing Facilities (2)		(0.04	)
Charges Associated with Exelon’s Anticipated Merger with PSEG (3)		0.01
2005 Adjusted (non-GAAP) Operating Earnings		0.75
Year Over Year Effects on Earnings:
ComEd Energy Margins:
Weather (4)		(0.03	)
Other Energy Delivery (5)		0.04
Net SECA Revenues (6)		(0.01	)
PECO Energy Margins:
Weather (7)		(0.01	)
Other Energy Delivery (8)		0.04
Generation Energy Margins, Excluding Mark-to-Market (9)		0.16
Stock-Based Compensation (10)		(0.02	)
Asbestos Reserve (11)		0.04
Other Operating and Maintenance Expense (12)		(0.03	)
Depreciation and Amortization (13)		(0.05	)
Interest Expense (14)		(0.01	)
Nuclear Decommissioning Trust Fund Rebalancing (15)		(0.03	)
Taxes Other Than Income (16)		0.01
2006 Adjusted (non-GAAP) Operating Earnings		0.85
2006 Adjusted (non-GAAP) Operating Earnings Adjustments:
Mark-to-Market (1)		0.06
Investments in Synthetic Fuel-Producing Facilities (2)		(0.08	)
Charges Associated with Exelon’s Anticipated Merger with PSEG (3)		(0.01	)
Nuclear Decommissioning Obligation Reduction (17)		0.13
2006 GAAP Earnings per Diluted Share	$	0.95

(1)	Reflects the mark-to-market impact of Exelon’s non-trading activities.
(2)	Reflects the financial impact of Exelon’s investments in synthetic fuel-producing facilities, including the impact of mark-to-market gains associated with the related derivatives and a $69 million impairment charge (after tax) in 2006.
(3)	Reflects certain costs incurred in connection with Exelon’s proposed merger with PSEG.
(4)	Reflects unfavorable weather conditions in the ComEd service territory.
(5)	Reflects increased revenues net of fuel at ComEd primarily due to changes in customer usage and mix, increased residential deliveries (excluding the impact of weather) and increased net transmission revenues. Although customer rates are frozen through 2006, average effective customer rates fluctuate due to the usage patterns of customers. Excludes the effects of the 2006 change in the purchased power agreement with Generation.
(6)	Reflects a decrease in net recognized SECA revenues.
(7)	Reflects unfavorable weather conditions in the PECO service territory.
(8)	Reflects increased revenues at PECO primarily due to authorized electric rate increases, including scheduled CTC rate increases in accordance with PECO’s 1998 restructuring settlement with the PAPUC.
(9)	Reflects higher realized prices on market sales and higher nuclear volumes at Generation. Excludes the impact of the 2006 change in the purchased power agreement with ComEd.
(10)	Reflects increased stock-based compensation costs.
(11)	Reflects the 2005 impact on net income of a reserve recorded by Generation for estimated future asbestos-related bodily injury claims.
(12)	Reflects increased operating and maintenance expense primarily due to inflation and increased bad debt expense at PECO.
(13)	Reflects increased depreciation and amortization primarily due to increased CTC amortization at PECO.
(14)	Reflects increased interest expense, primarily at Generation.
(15)	Reflects the 2005 impact on net income of gains realized on AmerGen’s decommissioning trust fund investments related to changes to the investment strategy.
(16)	Reflects decreased taxes other than income primarily due to favorable tax settlements at PECO in 2006.
(17)	Reflects a decrease in Generation’s nuclear decommissioning obligation liability related to the AmerGen nuclear plants.

9

EXELON CORPORATION

Reconciliation of Adjusted (non-GAAP) Operating Earnings
to GAAP Earnings By Business Segment (in millions)

Three Months Ended June 30, 2006 and 2005

	ComEd			PECO			Generation			Other			Exelon
2005 GAAP Earnings	$	109		$	110		$	296		$	(1	)	$	514
2005 Adjusted (non-GAAP) Operating Earnings Adjustments:
Mark-to-Market (1)		—			—			14			—			14
Investments in Synthetic Fuel-Producing Facilities (2)		—			—			—			(29	)		(29	)
Charges Associated with Exelon’s Anticipated Merger with PSEG (3)		—			4			1			—			5
Severance Charges (4)		(2	)		—			1			2			1
2005 Financial Impact of Generation’s Prior Investment in Sithe (5)		—			—			1			—			1
2005 Adjusted (non-GAAP) Operating Earnings		107			114			313			(28	)		506
Year Over Year Effects on Earnings:
ComEd and PECO Energy Margins:
Weather (6)		(20	)		(6	)		—			—			(26	)
Other Energy Delivery (7)		26			24			—			—			50
Net SECA Revenues (8)		(4	)		1			—			—			(3	)
Generation Energy Margins, Excluding Mark-to-Market (9)		—			—			110			—			110
ComEd and Generation PPA Rate Change (10)		30			—			(30	)		—			—
Stock-Based Compensation (11)		(4	)		(1	)		(6	)		—			(11	)
Pension and Non-Pension Postretirement Benefits Expense (12)		1			—			(1	)		(1	)		(1	)
Asbestos Reserve (13)		—			—			27			—			27
Other Operating and Maintenance Expense (14)		(4	)		(14	)		(11	)		6			(23	)
Depreciation and Amortization (15)		(3	)		(23	)		(6	)		(1	)		(33	)
Interest Expense (16)		1			3			(6	)		(2	)		(4	)
Nuclear Decommissioning Trust Fund Rebalancing (17)		—			—			(21	)		—			(21	)
Taxes Other Than Income (18)		1			5			(1	)		—			5
Other		(5	)		(7	)		7			6			1
2006 Adjusted (non-GAAP) Operating Earnings		126			96			375			(20	)		577
2006 Adjusted (non-GAAP) Operating Earnings Adjustments:
Mark-to-Market (1)		2			—			36			—			38
Investments in Synthetic Fuel-Producing Facilities (2)		—			—			—			(55	)		(55	)
Charges Associated with Exelon’s Anticipated Merger with PSEG (3)		(1	)		(3	)		(2	)		(1	)		(7	)
Nuclear Decommissioning Obligation Reduction (19)		—			—			89			—			89
2006 Financial Impact of Generation’s Prior Investment in Sithe (5)		—			—			2			—			2
2006 GAAP Earnings	$	127		$	93		$	500		$	(76	)	$	644

(1)	Reflects the mark-to-market impact of Exelon’s non-trading activities.
(2)	Reflects the financial impact of Exelon’s investments in synthetic fuel-producing facilities, including the impact of mark-to-market gains associated with the related derivatives and a $69 million impairment charge (after tax) in 2006.
(3)	Reflects certain costs incurred in connection with Exelon’s proposed merger with PSEG.
(4)	Reflects severance charges recorded during the period or adjustments to previously recorded severance reserves.
(5)	Reflects the financial impact of Generation’s prior investment in Sithe (sold in January 2005).
(6)	Reflects unfavorable weather conditions in the ComEd and PECO service territories.
(7)	Reflects increased revenues net of fuel at ComEd primarily due to changes in customer usage and mix, increased residential deliveries (excluding the impact of weather) and increased net transmission revenues. Although customer rates are frozen through 2006, average effective customer rates fluctuate due to the usage patterns of customers. Excludes the effects and the 2006 change in the purchased power agreement with Generation. Also, reflects increased revenues at PECO primarily due to authorized electric rate increases, including scheduled CTC rate increases in accordance with PECO’s 1998 restructuring settlement with the PAPUC.
(8)	Reflects a decrease in net recognized SECA revenues.
(9)	Reflects higher realized prices on market sales and higher nuclear volumes at Generation. Excludes the impact of the 2006 change in the purchased power agreement with ComEd.
(10)	Reflects the impact on net income of decreased prices in accordance with ComEd’s purchased power agreement with Generation.
(11)	Reflects increased stock-based compensation costs.
(12)	Reflects increased pension and non-pension postretirement benefits expense primarily due to changes in actuarial assumptions in 2006.
(13)	Reflects the 2005 impact on net income of a reserve recorded by Generation for estimated future asbestos-related bodily injury claims.
(14)	Reflects increased operating and maintenance expense primarily due to inflation and increased bad debt expense at PECO.
(15)	Reflects increased depreciation and amortization primarily due to increased CTC amortization at PECO.
(16)	Reflects increased interest expense, primarily at Generation.
(17)	Reflects the 2005 impact on net income of gains realized on AmerGen’s decommissioning trust fund investments related to changes to the investment strategy.
(18)	Reflects decreased taxes other than income primarily due to favorable tax settlements at PECO in 2006.
(19)	Reflects a decrease in Generation’s nuclear decommissioning obligation liability related to the AmerGen nuclear plants.

10

EXELON CORPORATION

Reconciliation of Adjusted (non-GAAP) Operating Earnings

Per Diluted Share to GAAP Earnings Per Diluted Share

Six Months Ended June 30, 2006 and 2005

2005 GAAP Earnings per Diluted Share	$	1.53
2005 Adjusted (non-GAAP) Operating Earnings Adjustments:
Mark-to-Market (1)		(0.03	)
Investments in Synthetic Fuel-Producing Facilities (2)		(0.07	)
Charges Associated with Exelon’s Anticipated Merger with PSEG (3)		0.01
2005 Financial Impact of Generation’s Prior Investment in Sithe (4)		(0.02	)
2005 Adjusted (non-GAAP) Operating Earnings		1.42
Year Over Year Effects on Earnings:
ComEd Energy Margins:
Weather (5)		(0.04	)
Other Energy Delivery (6)		0.04
Net SECA Revenues (7)		(0.02	)
PECO Energy Margins:
Weather (8)		(0.04	)
Other Energy Delivery (9)		0.06
Generation Energy Margins, Excluding Mark-to-Market (10)		0.30
Stock-Based Compensation (11)		(0.04	)
Pension and Non-Pension Postretirement Benefits Expense (12)		(0.01	)
Asbestos Reserve (13)		0.04
Other Operating and Maintenance Expense (14)		(0.08	)
Depreciation and Amortization (15)		(0.09	)
Interest Expense (16)		(0.03	)
Nuclear Decommissioning Trust Fund Rebalancing (17)		(0.03	)
Taxes Other Than Income (18)		(0.01	)
Other		0.01
2006 Adjusted (non-GAAP) Operating Earnings		1.48
2006 Adjusted (non-GAAP) Operating Earnings Adjustments:
Mark-to-Market (1)		0.03
Investments in Synthetic Fuel-Producing Facilities (2)		(0.06	)
Charges Associated with Exelon’s Anticipated Merger with PSEG (3)		(0.02	)
Nuclear Decommissioning Obligation Reduction (19)		0.13
Severance Charges and 2006 Financial Impact of Generation’s Prior Investment in Sithe (4),(20)		(0.01	)
2006 GAAP Earnings per Diluted Share	$	1.55

(1)	Reflects the mark-to-market impact of Exelon’s non-trading activities.
(2)	Reflects the financial impact of Exelon’s investments in synthetic fuel-producing facilities, including the impact of mark-to-market gains associated with the related derivatives and a $69 million impairment charge (after tax) in 2006.
(3)	Reflects certain costs incurred in connection with Exelon’s proposed merger with PSEG.
(4)	Reflects the financial impact of Generation’s prior investment in Sithe (sold in January 2005).
(5)	Reflects unfavorable weather conditions in the ComEd service territory.
(6)	Reflects increased revenues net of fuel at ComEd primarily due to changes in customer usage and mix, increased residential deliveries (excluding the impact of weather) and increased net transmission revenues. Although customer rates are frozen through 2006, average effective customer rates fluctuate due to the usage patterns of customers. Excludes the effects of the 2006 change in the purchased power agreement with Generation.
(7)	Reflects a decrease in net recognized SECA revenues.
(8)	Reflects unfavorable weather conditions in the PECO service territory.
(9)	Reflects increased revenues at PECO primarily due to authorized electric rate increases, including scheduled CTC rate increases in accordance with PECO’s 1998 restructuring settlement with the PAPUC.
(10)	Reflects higher realized prices on market sales and higher nuclear volumes at Generation. Excludes the impact of the 2006 change in the purchased power agreement with ComEd.
(11)	Reflects increased stock-based compensation costs.
(12)	Reflects increased pension and non-pension postretirement benefits expense primarily due to changes in actuarial assumptions in 2006.
(13)	Reflects the 2005 impact on net income of a reserve recorded by Generation for estimated future asbestos-related bodily injury claims.
(14)	Reflects increased operating and maintenance expense primarily due to inflation, increased bad debt expense at PECO and increased costs at Generation associated with non-outage operating costs and nuclear refueling expenses.
(15)	Reflects increased depreciation and amortization primarily due to increased CTC amortization at PECO.
(16)	Primarily reflects interest expense associated with the debt issued to fund Exelon’s pension contribution that was made at the end of the first quarter of 2005.
(17)	Reflects the 2005 impact on net income of gains realized on AmerGen’s decommissioning trust fund investments related to changes to the investment strategy.
(18)	Reflects increased taxes other than income primarily due to favorable tax settlements at PECO and Generation in the first quarter of 2005, partially offset by favorable tax settlements at PECO in 2006.
(19)	Reflects a decrease in Generation’s nuclear decommissioning obligation liability related to the AmerGen nuclear plants.
(20)	Reflects severance charges recorded during the period or adjustments to previously recorded severance reserves.

11

EXELON CORPORATION

Reconciliation of Adjusted (non-GAAP) Operating Earnings
to GAAP Earnings By Business Segment (in millions)

Six Months Ended June 30, 2006 and 2005

	ComEd			PECO			Generation			Other			Exelon
2005 GAAP Earnings	$	179		$	239		$	616		$	1		$	1,035
2005 Adjusted (non-GAAP) Operating Earnings Adjustments:
Mark-to-Market (1)		—			—			(25	)		—			(25	)
Investments in Synthetic Fuel-Producing Facilities (2)		—			—			—			(45	)		(45	)
Charges Associated with Exelon’s Anticipated Merger with PSEG (3)		—			6			—			—			6
Severance Charges (4)		(2	)		1			1			1			1
2005 Financial Impact of Generation’s Prior Investment in Sithe (5)		—			—			(15	)		—			(15	)
2005 Adjusted (non-GAAP) Operating Earnings		177			246			577			(43	)		957
Year Over Year Effects on Earnings:
ComEd and PECO Energy Margins:
Weather (6)		(24	)		(25	)		—			—			(49	)
Other Energy Delivery (7)		29			42			—			—			71
Net SECA Revenues (8)		(14	)		1			—			—			(13	)
Generation Energy Margins, Excluding Mark-to-Market (9)		—			—			202			—			202
ComEd and Generation PPA Rate Change (10)		48			—			(48	)		—			—
Stock-Based Compensation (11)		(8	)		(5	)		(14	)		—			(27	)
Pension and Non-Pension Postretirement Benefits Expense (12)		—			(2	)		(4	)		—			(6	)
Asbestos Reserve (13)		—			—			27			—			27
Other Operating and Maintenance Expense (14)		(5	)		(17	)		(37	)		4			(55	)
Depreciation and Amortization (15)		(4	)		(46	)		(10	)		(2	)		(62	)
Interest Expense (16)		1			5			(11	)		(15	)		(20	)
Nuclear Decommissioning Trust Fund Rebalancing (17)		—			—			(21	)		—			(21	)
Taxes Other Than Income (18)		(1	)		(1	)		(6	)		(1	)		(9	)
Other		(12	)		(4	)		9			9			2
2006 Adjusted (non-GAAP) Operating Earnings		187			194			664			(48	)		997
2006 Adjusted (non-GAAP) Operating Earnings Adjustments:
Mark-to-Market (1)		(5	)		—			23			—			18
Investments in Synthetic Fuel-Producing Facilities (2)		—			—			—			(42	)		(42	)
Charges Associated with Exelon’s Anticipated Merger with PSEG (3)		(2	)		(7	)		(6	)		(1	)		(16	)
Nuclear Decommissioning Obligation Reduction (19)		—			—			89			—			89
Severance Charges (4)		1			(1	)		(1	)		—			(1	)
2006 Financial Impact of Generation’s Prior Investment in Sithe (5)		—			—			(1	)		—			(1	)
2006 GAAP Earnings	$	181		$	186		$	768		$	(91	)	$	1,044

(1)	Reflects the mark-to-market impact of Exelon’s non-trading activities.
(2)	Reflects the financial impact of Exelon’s investments in synthetic fuel-producing facilities, including the impact of mark-to-market gains associated with the related derivatives and a $69 million impairment charge (after tax) in 2006.
(3)	Reflects certain costs incurred in connection with Exelon’s proposed merger with PSEG.
(4)	Reflects severance charges recorded during the period or adjustments to previously recorded severance reserves.
(5)	Reflects the financial impact of Generation’s prior investment in Sithe (sold in January 2005).
(6)	Reflects unfavorable weather conditions in the ComEd and PECO service territories.
(7)	Reflects increased revenues net of fuel at ComEd primarily due to changes in customer usage and mix, increased residential deliveries (excluding the impact of weather) and increased net transmission revenues. Although customer rates are frozen through 2006, average effective customer rates fluctuate due to the usage patterns of customers. Excludes the effects of the 2006 change in the purchased power agreement with Generation. Also, reflects increased revenues at PECO primarily due to authorized electric rate increases, including scheduled CTC rate increases in accordance with PECO’s 1998 restructuring settlement with the PAPUC.
(8)	Reflects a decrease in net recognized SECA revenues.
(9)	Reflects higher realized prices on market sales and higher nuclear volumes at Generation. Excludes the impact of the 2006 change in the purchased power agreement with ComEd.
(10)	Reflects the impact on net income of decreased prices in accordance with ComEd’s purchased power agreement with Generation.
(11)	Reflects increased stock-based compensation costs.
(12)	Reflects increased pension and non-pension postretirement benefits expense primarily due to changes in actuarial assumptions in 2006.
(13)	Reflects the 2005 impact on net income of a reserve recorded by Generation for estimated future asbestos-related bodily injury claims.
(14)	Reflects increased operating and maintenance expense primarily due to inflation, increased bad debt expense at PECO and increased costs at Generation associated with non-outage operating costs and nuclear refueling expenses.
(15)	Reflects increased depreciation and amortization primarily due to increased CTC amortization at PECO.
(16)	Primarily reflects interest expense associated with the debt issued to fund Exelon’s pension contribution that was made at the end of the first quarter of 2005.
(17)	Reflects the 2005 impact on net income of gains realized on AmerGen’s decommissioning trust fund investments related to changes to the investment strategy.
(18)	Reflects increased taxes other than income primarily due to favorable tax settlements at PECO and Generation in the first quarter of 2005, partially offset by favorable tax settlements at PECO in 2006.
(19)	Reflects a decrease in Generation’s nuclear decommissioning obligation liability related to the AmerGen nuclear plants.

12

EXELON CORPORATION
Reconciliation of Adjusted (non-GAAP) Operating Earnings to
GAAP Consolidated Statements of Income
(unaudited)
(in millions)

	ComEd
	Three Months Ended June 30, 2006										Three Months Ended June 30, 2005
								Adjusted										Adjusted
	GAAP (a)			Adjustments				Non-GAAP			GAAP (a)			Adjustments				Non-GAAP
Operating revenues	$	1,453		$	(3	)	(b)	$	1,450		$	1,488		$	—			$	1,488
Operating expenses
Purchased power		766			—				766			858			—				858
Operating and maintenance		218			(2	)	(c)		216			202			3		(d)		205
Depreciation and amortization		106			—				106			101			—				101
Taxes other than income		71			—				71			73			—				73
Total operating expenses		1,161			(2	)			1,159			1,234			3				1,237
Operating income		292			(1	)			291			254			(3	)			251
Other income and deductions
Interest expense		(77	)		—				(77	)		(77	)		—				(77	)
Equity in losses of unconsolidated affiliates		(3	)		—				(3	)		(4	)		—				(4	)
Other, net		1			—				1			7			—				7
Total other income and deductions		(79	)		—				(79	)		(74	)		—				(74	)
Income before income taxes		213			(1	)			212			180			(3	)			177
Income taxes		86			—		(b),(c)		86			71			(1	)	(d)		70
Net income	$	127		$	(1	)		$	126		$	109		$	(2	)		$	107
	Six Months Ended June 30, 2006										Six Months Ended June 30, 2005
								Adjusted										Adjusted
	GAAP (a)			Adjustments				Non-GAAP			GAAP (a)			Adjustments				Non-GAAP
Operating revenues	$	2,880		$	8		(b)	$	2,888		$	2,875		$	—			$	2,875
Operating expenses
Purchased power		1,628			—				1,628			1,679			—				1,679
Operating and maintenance		434			(3	)	(c),(d)		431			404			4		(d)		408
Depreciation and amortization		205			—				205			198			—				198
Taxes other than income		152			—				152			151			—				151
Total operating expenses		2,419			(3	)			2,416			2,432			4				2,436
Operating income		461			11				472			443			(4	)			439
Other income and deductions
Interest expense		(153	)		—				(153	)		(151	)		—				(151	)
Equity in losses of unconsolidated affiliates		(5	)		—				(5	)		(8	)		—				(8	)
Other, net		1			—				1			13			—				13
Total other income and deductions		(157	)		—				(157	)		(146	)		—				(146	)
Income (loss) before income taxes		304			11				315			297			(4	)			293
Income taxes		123			5		(b),(c),(d)		128			118			(2	)	(d)		116
Net income	$	181		$	6			$	187		$	179		$	(2	)		$	177

(a)	Results reported in accordance with GAAP.
(b)	Adjustment to exclude the mark-to-market impact of one wholesale contract at ComEd.
(c)	Adjustment to exclude certain costs associated with Exelon’s anticipated merger with PSEG.
(d)	Adjustment to exclude severance charges and adjustments to previously recorded severance reserves.

13

EXELON CORPORATION
Reconciliation of Adjusted (non-GAAP) Operating Earnings to
GAAP Consolidated Statements of Income
(unaudited)
(in millions)

	PECO
	Three Months Ended June 30, 2006										Three Months Ended June 30, 2005
								Adjusted										Adjusted
	GAAP (a)			Adjustments				Non-GAAP			GAAP (a)			Adjustments				Non-GAAP
Operating revenues	$	1,148		$	—			$	1,148		$	1,044		$	—			$	1,044
Operating expenses
Purchased power		501			—				501			437			—				437
Fuel		76			—				76			66			—				66
Operating and maintenance		141			(2	)	(b)		139			119			(3	)	(b)		116
Depreciation and amortization		172			(3	)	(b)		169			137			(3	)	(b)		134
Taxes other than income		53			—				53			60			—				60
Total operating expenses		943			(5	)			938			819			(6	)			813
Operating income		205			5				210			225			6				231
Other income and deductions
Interest expense		(67	)		—				(67	)		(70	)		—				(70	)
Equity in losses of unconsolidated affiliates		(2	)		—				(2	)		(4	)		—				(4	)
Other, net		2			—				2			6			—				6
Total other income and deductions		(67	)		—				(67	)		(68	)		—				(68	)
Income before income taxes		138			5				143			157			6				163
Income taxes		45			2		(b)		47			47			2		(b)		49
Net income	$	93		$	3			$	96		$	110		$	4			$	114
	Six Months Ended June 30, 2006										Six Months Ended June 30, 2005
								Adjusted										Adjusted
	GAAP (a)			Adjustments				Non-GAAP			GAAP (a)			Adjustments				Non-GAAP
Operating revenues	$	2,554		$	—			$	2,554		$	2,339		$	—			$	2,339
Operating expenses
Purchased power		987			—				987			869			—				869
Fuel		402			—				402			331			—				331
Operating and maintenance		289			(5	)	(b),(c)		284			253			(4	)	(b),(c)		249
Depreciation and amortization		343			(7	)	(b)		336			273			(6	)	(b)		267
Taxes other than income		117			—				117			115			—				115
Total operating expenses		2,138			(12	)			2,126			1,841			(10	)			1,831
Operating income		416			12				428			498			10				508
Other income and deductions
Interest expense		(136	)		—				(136	)		(142	)		—				(142	)
Equity in losses of unconsolidated affiliates		(6	)		—				(6	)		(8	)		—				(8	)
Other, net		5			—				5			9			—				9
Total other income and deductions		(137	)		—				(137	)		(141	)		—				(141	)
Income before income taxes		279			12				291			357			10				367
Income taxes		93			4		(b),(c)		97			118			3		(b),(c)		121
Net income	$	186		$	8			$	194		$	239		$	7			$	246

(a)	Results reported in accordance with GAAP.
(b)	Adjustment to exclude certain costs associated with Exelon’s anticipated merger with PSEG.
(c)	Adjustment to exclude severance charges.

14

EXELON CORPORATION
Reconciliation of Adjusted (non-GAAP) Operating Earnings to
GAAP Consolidated Statements of Income
(unaudited)
(in millions)

	Generation
	Three Months Ended June 30, 2006										Three Months Ended June 30, 2005
								Adjusted										Adjusted
	GAAP (a)			Adjustments				Non-GAAP			GAAP (a)			Adjustments				Non-GAAP
Operating revenues	$	2,214		$	—			$	2,214		$	2,105		$	—			$	2,105
Operating expenses
Purchased power		418			49		(b)		467			517			15		(b)		532
Fuel		425			9		(b)		434			428			(37	)	(b)		391
Operating and maintenance		440			144		(c),(d)		584			602			(3	)	(c),(f)		599
Depreciation and amortization		72			—				72			63			—				63
Taxes other than income		41			—				41			39			—				39
Total operating expenses		1,396			202				1,598			1,649			(25	)			1,624
Operating income		818			(202	)			616			456			25				481
Other income and deductions
Interest expense		(40	)		1		(e)		(39	)		(29	)		—				(29	)
Equity in gains (losses) of unconsolidated affiliates		(1	)		—				(1	)		4			—				4
Other, net		14			—				14			51			—				51
Total other income and deductions		(27	)		1				(26	)		26			—				26
Income from continuing operations before income taxes		791			(201	)			590			482			25				507
Income taxes		294			(79	)	(b),(c),(d),(e)		215			185			9		(b),(c),(f)		194
Income from continuing operations		497			(122	)			375			297			16				313
Income (loss) from discontinued operations		3			(3	)	(e)		—			(1	)		1		(e)		—
Net income	$	500		$	(125	)		$	375		$	296		$	17			$	313
	Six Months Ended June 30, 2006										Six Months Ended June 30, 2005
								Adjusted										Adjusted
	GAAP (a)			Adjustments				Non-GAAP			GAAP (a)			Adjustments				Non-GAAP
Operating revenues	$	4,434		$	—			$	4,434		$	4,125		$	—			$	4,125
Operating expenses
Purchased power		781			88		(b)		869			967			(4	)	(b)		963
Fuel		1,036			(52	)	(b)		984			786			45		(b)		831
Operating and maintenance		1,108			142		(c),(d),(f)		1,250			1,211			(3	)	(c),(f)		1,208
Depreciation and amortization		139			—				139			125			—				125
Taxes other than income		84			—				84			74			—				74
Total operating expenses		3,148			178				3,326			3,163			38				3,201
Operating income		1,286			(178	)			1,108			962			(38	)			924
Other income and deductions
Interest expense		(82	)		7		(e)		(75	)		(58	)		—				(58	)
Equity in gains (losses) of unconsolidated affiliates		(5	)		—				(5	)		4			—				4
Other, net		20			4		(c)		24			69			—				69
Total other income and deductions		(67	)		11				(56	)		15			—				15
Income from continuing operations before income taxes		1,219			(167	)			1,052			977			(38	)			939
Income taxes		454			(66	)	(b),(c),(d),(e),(f)		388			376			(14	)	(b),(c),(f)		362
Income from continuing operations		765			(101	)			664			601			(24	)			577
Income from discontinued operations		3			(3	)	(e)		—			15			(15	)	(e)		—
Net income	$	768		$	(104	)		$	664		$	616		$	(39	)		$	577

(a)	Results reported in accordance with GAAP.
(b)	Adjustment to exclude the mark-to-market impact of Generation’s non-trading activities.
(c)	Adjustment to exclude certain costs associated with Exelon’s anticipated merger with PSEG.
(d)	Adjustment to exclude the decrease in Generation’s nuclear decommissioning obligation liability related to the AmerGen nuclear plants.
(e)	Adjustment to exclude the financial impact of Generation’s prior investment in Sithe (sold in January 2005).
(f)	Adjustment to exclude severance charges.

15

EXELON CORPORATION
Reconciliation of Adjusted (non-GAAP) Operating Earnings to
GAAP Consolidated Statements of Income
(unaudited)
(in millions)

	Other
	Three Months Ended June 30, 2006										Three Months Ended June 30, 2005
								Adjusted										Adjusted
	GAAP (a)			Adjustments				Non-GAAP			GAAP (a)			Adjustments				Non-GAAP
Operating revenues	$	(1,118	)	$	—			$	(1,118	)	$	(1,153	)	$	—			$	(1,153	)
Operating expenses
Purchased power		(1,114	)		—				(1,114	)		(1,149	)		—				(1,149	)
Fuel		1			—				1			(1	)		—				(1	)
Operating and maintenance		82			(97	)	(b),(c)		(15	)		6			(13	)	(b),(d)		(7	)
Depreciation and amortization		21			(11	)	(b)		10			24			(16	)	(b)		8
Taxes other than income		5			—				5			5			—				5
Total operating expenses		(1,005	)		(108	)			(1,113	)		(1,115	)		(29	)			(1,144	)
Operating loss		(113	)		108				(5	)		(38	)		29				(9	)
Other income and deductions
Interest expense		(38	)		3		(b)		(35	)		(34	)		4		(b)		(30	)
Equity in losses of unconsolidated affiliates		(16	)		16		(b)		—			(28	)		28		(b)		—
Other, net		29			(24	)	(b)		5			4			—				4
Total other income and deductions		(25	)		(5	)			(30	)		(58	)		32				(26	)
Loss from continuing operations before income taxes		(138	)		103				(35	)		(96	)		61				(35	)
Income taxes		(62	)		47		(b),(c)		(15	)		(96	)		88		(b),(d)		(8	)
Loss from continuing operations		(76	)		56				(20	)		—			(27	)			(27	)
Loss from discontinued operations		—			—				—			(1	)		—				(1	)
Net income (loss)	$	(76	)	$	56			$	(20	)	$	(1	)	$	(27	)		$	(28	)
	Six Months Ended June 30, 2006										Six Months Ended June 30, 2005
								Adjusted										Adjusted
	GAAP (a)			Adjustments				Non-GAAP			GAAP (a)			Adjustments				Non-GAAP
Operating revenues	$	(2,309	)	$	—			$	(2,309	)	$	(2,294	)	$	—			$	(2,294	)
Operating expenses
Purchased power		(2,300	)		—				(2,300	)		(2,283	)		—				(2,283	)
Fuel		—			—				—			(2	)		—				(2	)
Operating and maintenance		75			(101	)	(b),(c)		(26	)		9			(30	)	(b),(d)		(21	)
Depreciation and amortization		48			(28	)	(b)		20			48			(31	)	(b)		17
Taxes other than income		11			—				11			9			—				9
Total operating expenses		(2,166	)		(129	)			(2,295	)		(2,219	)		(61	)			(2,280	)
Operating loss		(143	)		129				(14	)		(75	)		61				(14	)
Other income and deductions
Interest expense		(74	)		5		(b)		(69	)		(48	)		8		(b)		(40	)
Equity in gains (losses) of unconsolidated affiliates		(45	)		46		(b)		1			(56	)		56		(b)		—
Other, net		65			(53	)	(b)		12			6			—				6
Total other income and deductions		(54	)		(2	)			(56	)		(98	)		64				(34	)
Loss from continuing operations before income taxes		(197	)		127				(70	)		(173	)		125				(48	)
Income taxes		(106	)		84		(b),(c)		(22	)		(177	)		169		(b),(d)		(8	)
Income (loss) from continuing operations		(91	)		43				(48	)		4			(44	)			(40	)
Loss from discontinued operations		—			—				—			(3	)		—				(3	)
Net income (loss)	$	(91	)	$	43			$	(48	)	$	1		$	(44	)		$	(43	)

(a)	Results reported in accordance with GAAP.
(b)	Adjustment to exclude the financial impact of Exelon’s investments in synthetic fuel-producing facilities, including the impact of mark-to-market gains associated with the related derivatives.
(c)	Adjustment to exclude certain costs associated with Exelon’s anticipated merger with PSEG.
(d)	Adjustment to exclude severance charges.

16

EXELON CORPORATION
Electric Sales Statistics

	Three Months Ended June 30,
(in GWhs)	2006			2005			% Change
Supply
Nuclear		35,442			34,685			2.2	%
Purchased Power — Generation (a)		8,101			9,061			(10.6	%)
Fossil and Hydro		3,148			3,246			(3.0	%)
Power Team Supply		46,691			46,992			(0.6	%)
Purchased Power — Other		370			225			64.4	%
Total Electric Supply Available for Sale		47,061			47,217			(0.3	%)
Less: Line Loss and Company Use		(2,550	)		(2,721	)		(6.3	%)
Total Supply		44,511			44,496			0.0	%
Energy Sales
Retail Sales		31,888			32,255			(1.1	%)
Power Team Market Sales (a)		17,065			16,912			0.9	%
Interchange Sales and Sales to Other Utilities		809			689			17.4	%
		49,762			49,856			(0.2	%)
Less: Distribution Only Sales		(5,251	)		(5,360	)		(2.0	%)
Total Energy Sales		44,511			44,496			0.0	%

	Six Months Ended June 30,
(in GWhs)	2006			2005			% Change
Supply
Nuclear		68,933			67,465			2.2	%
Purchased Power — Generation (a)		15,870			18,607			(14.7	%)
Fossil and Hydro		6,119			6,383			(4.1	%)
Power Team Supply		90,922			92,455			(1.7	%)
Purchased Power — Other		689			411			67.6	%
Total Electric Supply Available for Sale		91,611			92,866			(1.4	%)
Less: Line Loss and Company Use		(5,086	)		(4,466	)		13.9	%
Total Supply		86,525			88,400			(2.1	%)
Energy Sales
Retail Sales		64,232			65,448			(1.9	%)
Power Team Market Sales (a)		30,045			32,557			(7.7	%)
Interchange Sales and Sales to Other Utilities		1,562			1,268			23.2	%
		95,839			99,273			(3.5	%)
Less: Distribution Only Sales		(9,314	)		(10,873	)		(14.3	%)
Total Energy Sales		86,525			88,400			(2.1	%)

(a) Purchased power and market sales do not include trading volume of 7,769 GWhs and 5,660 GWhs for the three months ended June 30, 2006 and 2005, respectively, and 14,754 GWhs and 11,411 GWhs for the six months ended June 30, 2006 and 2005, respectively.

17

EXELON CORPORATION
ComEd and PECO Sales Statistics
Three Months Ended June 30, 2006 and 2005

	ComEd									PECO
Electric Deliveries (in GWhs)	2006			2005			% Change			2006		2005		% Change
Full Service (a)
Residential		6,124			6,235			(1.8	%)		2,719		2,686		1.2	%
Small Commercial & Industrial		5,709			5,103			11.9	%		1,869		1,730		8.0	%
Large Commercial & Industrial		2,430			2,103			15.5	%		3,875		3,705		4.6	%
Public Authorities & Electric Railroads		514			521			(1.3	%)		229		205		11.7	%
Total Full Service		14,777			13,962			5.8	%		8,692		8,326		4.4	%
PPO (ComEd Only)
Small Commercial & Industrial		814			1,433			(43.2	%)
Large Commercial & Industrial		675			1,635			(58.7	%)
		1,489			3,068			(51.5	%)
Delivery Only (b)
Residential		(d	)		(d	)					14		74		(81.1	%)
Small Commercial & Industrial		1,291			1,495			(13.6	%)		163		315		(48.3	%)
Large Commercial & Industrial		3,772			3,330			13.3	%		11		146		(92.5	%)
		5,063			4,825			4.9	%		188		535		(64.9	%)
Total PPO and Delivery Only		6,552			7,893			(17.0	%)		188		535		(64.9	%)
Total Retail Deliveries		21,329			21,855			(2.4	%)		8,880		8,861		0.2	%
Gas Deliveries (mmcf) (PECO only)											12,431		13,417		(7.3	%)
Revenue (in millions)
Full Service (a)
Residential	$	547		$	559			(2.1	%)	$	392	$	359		9.2	%
Small Commercial & Industrial		452			413			9.4	%		236		203		16.3	%
Large Commercial & Industrial		130			105			23.8	%		319		283		12.7	%
Public Authorities & Electric Railroads		32			32			0.0	%		22		19		15.8	%
Total Full Service		1,161			1,109			4.7	%		969		864		12.2	%
PPO (ComEd Only) (c)
Small Commercial & Industrial		61			99			(38.4	%)
Large Commercial & Industrial		42			93			(54.8	%)
		103			192			(46.4	%)
Delivery Only (b)
Residential		(d	)		(d	)					1		6		(83.3	%)
Small Commercial & Industrial		21			27			(22.2	%)		9		17		(47.1	%)
Large Commercial & Industrial		40			41			(2.4	%)		1		4		(75.0	%)
		61			68			(10.3	%)		11		27		(59.3	%)
Total PPO and Delivery Only		164			260			(36.9	%)		11		27		(59.3	%)
Total Retail Electric Revenue		1,325			1,369			(3.2	%)		980		891		10.0	%
Wholesale and Miscellaneous Revenue (e)		125			119			5.0	%		60		53		13.2	%
Mark-to-market wholesale contract		3			—			n.m.			—		—		0.0	%
Gas Revenue (PECO only)		n/a			n/a						108		100		8.0	%
Total Revenues	$	1,453		$	1,488			(2.4	%)	$	1,148	$	1,044		10.0	%
Heating and Cooling Degree-Days	2006			2005			Normal			2006		2005		Normal
Heating Degree-Days		617			664			794			335		484		488
Cooling Degree-Days		212			314			216			327		327		316

(a)	Full service reflects deliveries to customers taking electric service under tariffed rates which include the cost of energy and the cost of the transmission and distribution of the energy. PECO’s tariffed rates also include a competitive transition charge (CTC).
(b)	Delivery only service reflects customers electing to receive electric generation service from an alternative energy supplier. Revenue from customers choosing an alternative energy supplier includes a distribution charge and a CTC.
(c)	Revenue from customers choosing ComEd’s purchase power option (PPO) includes an energy charge at market rates, transmission and distribution charges and a CTC.
(d)	All ComEd residential customers are eligible to choose their supplier of electricity. As of June 30, 2006, one alternative supplier was approved to serve residential customers in the ComEd service territory. However, no residential customers have selected this alternative supplier.
(e)	Wholesale and miscellaneous revenue includes transmission revenue from PJM Interconnection, LLC (PJM), sales to municipalities and other wholesale energy sales.
	n.m. — Not meaningful
	n/a — Not applicable

18

EXELON CORPORATION
ComEd and PECO Sales Statistics
Six Months Ended June 30, 2006 and 2005

	ComEd									PECO
Electric Deliveries (in GWhs)	2006			2005			% Change			2006		2005		% Change
Full Service (a)
Residential		12,921			13,346			(3.2	%)		5,917		5,955		(0.6	%)
Small Commercial & Industrial		11,028			10,211			8.0	%		3,753		3,462		8.4	%
Large Commercial & Industrial		4,609			3,883			18.7	%		7,576		7,214		5.0	%
Public Authorities & Electric Railroads		1,115			1,052			6.0	%		472		431		9.5	%
Total Full Service		29,673			28,492			4.1	%		17,718		17,062		3.8	%
PPO (ComEd Only)
Small Commercial & Industrial		2,322			2,458			(5.5	%)
Large Commercial & Industrial		2,198			3,119			(29.5	%)
		4,520			5,577			(19.0	%)
Delivery Only (b)
Residential		(d	)		(d	)					32		178		(82.0	%)
Small Commercial & Industrial		2,185			3,163			(30.9	%)		345		712		(51.5	%)
Large Commercial & Industrial		6,723			6,488			3.6	%		29		332		(91.3	%)
		8,908			9,651			(7.7	%)		406		1,222		(66.8	%)
Total PPO and Delivery Only		13,428			15,228			(11.8	%)		406		1,222		(66.8	%)
Total Retail Deliveries		43,101			43,720			(1.4	%)		18,124		18,284		(0.9	%)
Gas Deliveries (mmcf) (PECO only)											44,232		51,096		(13.4	%)
Revenue (in millions)
Full Service (a)
Residential	$	1,096		$	1,124			(2.5	%)	$	795	$	744		6.9	%
Small Commercial & Industrial		839			784			7.0	%		446		386		15.5	%
Large Commercial & Industrial		240			193			24.4	%		614		546		12.5	%
Public Authorities & Electric Railroads		68			65			4.6	%		43		40		7.5	%
Total Full Service		2,243			2,166			3.6	%		1,898		1,716		10.6	%
PPO (ComEd Only) (c)
Small Commercial & Industrial		163			165			(1.2	%)
Large Commercial & Industrial		132			171			(22.8	%)
		295			336			(12.2	%)
Delivery Only (b)
Residential		(d	)		(d	)					2		13		(84.6	%)
Small Commercial & Industrial		33			58			(43.1	%)		18		35		(48.6	%)
Large Commercial & Industrial		67			80			(16.3	%)		1		9		(88.9	%)
		100			138			(27.5	%)		21		57		(63.2	%)
Total PPO and Delivery Only		395			474			(16.7	%)		21		57		(63.2	%)
Total Retail Electric Revenue		2,638			2,640			(0.1	%)		1,919		1,773		8.2	%
Wholesale and Miscellaneous Revenue (e)		250			235			6.4	%		118		105		12.4	%
Mark-to-market wholesale contract		(8	)		—			n.m.			—		—		0.0	%
Gas Revenue (PECO only)		n/a			n/a						517		461		12.1	%
Total Revenues	$	2,880		$	2,875			0.2	%	$	2,554	$	2,339		9.2	%
Heating and Cooling Degree-Days	2006			2005			Normal			2006		2005		Normal
Heating Degree-Days		3,358			3,744			4,060			2,522		3,108		3,047
Cooling Degree-Days		212			315			217			328		327		316

(a)	Full service reflects deliveries to customers taking electric service under tariffed rates which include the cost of energy and the cost of the transmission and distribution of the energy. PECO’s tariffed rates also include a CTC.
(b)	Delivery only service reflects customers electing to receive electric generation service from an alternative energy supplier. Revenue from customers choosing an alternative energy supplier includes a distribution charge and a CTC.
(c)	Revenue from customers choosing ComEd’s PPO includes an energy charge at market rates, transmission and distribution charges and a CTC.
(d)	All ComEd residential customers are eligible to choose their supplier of electricity. As of June 30, 2006, one alternative supplier was approved to serve residential customers in the ComEd service territory. However, no residential customers have selected this alternative supplier.
(e)	Wholesale and miscellaneous revenue includes transmission revenue from PJM, sales to municipalities and other wholesale energy sales.
	n.m. — Not meaningful
	n/a — Not applicable

19

EXELON CORPORATION
Exelon Generation Power Marketing Statistics

	Three Months Ended
	June 30, 2006		March 31, 2006		December 31, 2005		September 30, 2005		June 30, 2005
GWh Sales
ComEd		18,685		20,309		19,749		24,331		19,625
PECO		9,262		9,615		9,404		11,442		8,957
Market and Retail Sales		18,744		14,308		17,431		19,525		18,410
Total Sales (a)		46,691		44,232		46,584		55,298		46,992
Average Margin ($/MWh)
Average Realized Revenue
ComEd	$	35.80	$	37.22	$	32.56	$	39.87	$	38.47
PECO		46.32		43.27		42.32		44.84		42.20
Market and Retail Sales (b)		50.31		52.14		49.34		53.16		42.53
Total Sales — without trading		43.71		43.36		40.81		45.61		40.77
Average Purchased Power and Fuel Cost — without trading (c)	$	17.28	$	15.94	$	18.78	$	27.09	$	17.71
Average Margin — without trading (c)	$	26.43	$	27.42	$	22.03	$	18.52	$	23.06
Around-the-clock Market Prices ($/MWh)
PECO — PJM West Hub	$	48.07	$	56.42	$	73.87	$	75.33	$	47.30
ComEd — NIHUB		39.28		42.48		52.81		54.75		38.35

(a)	Total sales do not include trading volume of 7,769 GHws, 6,985 GWhs, 8,756 GWhs, 6,757 GWhs and 5,660 GWhs for the three months ended June 30, 2006, March 31, 2006, December 31, 2005, September 30, 2005 and June 30, 2005, respectively.
(b)	Market and retail sales exclude revenues related to tolling agreements of $34 million, $52 million and $34 million for the three months ended June 30, 2006, September 30, 2005 and June 30, 2005, respectively.
(c)	Excludes the mark-to-market impact of Generation’s non-trading activities.

20

EXELON CORPORATION
Exelon Generation Power Marketing Statistics

	Six Months Ended June 30,
	2006		2005
GWh Sales
ComEd		38,994		38,718
PECO		18,876		18,317
Market and Retail Sales		33,052		35,420
Total Sales (a)		90,922		92,455
Average Margin ($/MWh)
Average Realized Revenue
ComEd	$	36.54	$	38.54
PECO		44.77		41.44
Market and Retail Sales (b)		51.10		40.74
Total Sales — without trading		43.54		39.95
Average Purchased Power and Fuel Cost — without trading (c)	$	16.63	$	16.48
Average Margin — without trading (c)	$	26.91	$	23.47
Around-the-clock Market Prices ($/MWh)
PECO — PJM West Hub	$	52.24	$	47.24
ComEd — NIHUB		40.88		39.01
2006 Forward market prices — July through December
Around-the-clock Market Prices ($/MWh)
PECO — PJM West Hub	$	56.80
ComEd — NIHUB		41.90
Gas Prices ($/Mmbtu)
Henry Hub	$	7.20

(a)	Total sales do not include trading volume of 14,754 GWhs and 11,411 GWhs for the six months ended June 30, 2006 and 2005, respectively.
(b)	Market and retail sales exclude revenues related to tolling agreements of $34 million for the six months ended June 30, 2006 and 2005.
(c)	Excludes the mark-to-market impact of Generation’s non-trading activities.

21

EX-99.2

Exhibit 99.2

EX-99.3

Exhibit 99.3

COMED RATE CASE DOCKET NO. 05-0597
ILLINOIS COMMERCE COMMISSION FINAL ORDER 7/26/06

SUMMARY

REVENUE REQUIREMENT & INCREASE

	Revenue Requirement	Revenue Increase
ICC Final Order	$1,586 million	$	8	million
ALJ Proposed Order*	$1,742 million	$	164	million
ComEd	$1,896 million	$	317	million

* The revenue requirement of $1,742 million reflects the ALJ Proposed Order after adjustments.

RATE BASE

	Gross Plant	Net Plant	Rate Base
ICC Final Order	$11,522 million	$6,927 million	$5,521 million
ALJ Proposed Order	$11,504 million	$6,909 million	$6,159 million
ComEd	$11,530 million	$6,935 million	$6,187 million

PENSION ASSET

	Allowance / Disallowance
ICC Final Order	Disallowed $853 million pension asset in rate base
ALJ Proposed Order	Same as ComEd
ComEd	Requested pension asset in rate base

     Reduction from ComEd’s Request ($317 million): $70 million

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COMED RATE CASE DOCKET NO. 05-0597
ILLINOIS COMMERCE COMMISSION FINAL ORDER 7/26/06

SUMMARY (Continued)

RATE OF RETURN & CAPITAL STRUCTURE

		Cost of
	Capital Structure	LT Debt			ROE			ROR
ICC Final Order	Common Equity 42.86%
	Long-Term Debt 57.14%		6.48	%		10.045	%		8.01	%
ALJ Proposed Order	Common Equity 46.00%
	Long-Term Debt 54.00%		6.50	%		10.19	%		8.20	%
ComEd	Common Equity 54.20%
	Long-Term Debt 45.80%		6.50	%		11.00	%		8.94	%

     Reduction from ComEd’s Request ($317 million): $125 million

ADMINISTRATIVE & GENERAL EXPENSES

	A&G Expense Recovery
ICC Final Order	$194 million
ALJ Proposed Order	Same as ComEd
ComEd	$255 million

     Reduction from ComEd’s Request ($317 million): $61 million

INCENTIVE COMPENSATION

	Incentive Compensation Recovery
ICC Final Order	$10 million
ALJ Proposed Order	Disallowed recovery of Incentive Compensation
ComEd	$20 million

     Reduction from ComEd’s Request ($317 million): $10 million

Page 2

COMED RATE CASE DOCKET NO. 05-0597
ILLINOIS COMMERCE COMMISSION FINAL ORDER 7/26/06

SUMMARY (Continued)

ICC FINAL ORDER COMPARISON TO COMED’S ORIGINAL REQUEST;
APPROVED REVENUE INCREASE ($8 MILLION)

Original Revenue Requirement Request	$	317	million
Adjustments:
Rate of Return / Capital Structure	($	125	) million
Pension Asset	($	70	) million
A&G Expenses	($	61	) million
Incentive Compensation	($	10	) million
ComEd Adjustments	($	38	) million
Miscellaneous Final Order Adjustments	($	5	) million
Approved Increase in Rate Revenues	$	8	million

Page 3