MIDWEST GENERATION LLC - 10-Q Quarterly Report

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

MIDWEST GENERATION, LLC
(Exact name of registrant as specified in its charter)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. YES ý NO o

Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Exchange Act). YES o NO ý

Number of units outstanding of the registrant's Membership Interests as of November 14, 2003: 100 units (all units held by an affiliate of the registrant).

		Page
PART I—Financial Information
Item 1.	Financial Statements	1
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	13
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	31
Item 4.	Controls and Procedures	31
PART II—Other Information
Item 6.	Exhibits and Reports on Form 8-K	32
	Signatures	33

MIDWEST GENERATION, LLC

STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(In thousands, Unaudited)

MIDWEST GENERATION, LLC

NOTES TO FINANCIAL STATEMENTS

SEPTEMBER 30, 2003

(Dollars in thousands, except as indicated; Unaudited)

In the opinion of management, all adjustments, including recurring accruals, have been made that are necessary to present fairly the financial position and results of operations for the periods covered by this report. The results of operations for the nine months ended September 30, 2003 are not necessarily indicative of the operating results for the full year.

Midwest Generation's significant accounting policies are described in Note 2 to its financial statements as of December 31, 2002 and 2001, included in its 2002 annual report on Form 10-K filed with the Securities and Exchange Commission, as amended by Amendment No. 1 on Form 10-K/A, which is referred to as Midwest Generation's 2002 annual report. Midwest Generation follows the same accounting policies for interim reporting purposes. This quarterly report should be read in connection with such financial statements. Terms used but not defined in this report are defined in Midwest Generation's 2002 annual report. Certain prior period amounts have been reclassified to conform to the current period financial statement presentation. These reclassifications had no effect on net income or member's equity.

A number of significant developments during late 2001 and 2002 adversely affected independent power producers and subsidiaries of major integrated energy companies that sell a sizable portion of their generation into the wholesale energy market (sometimes referred to as merchant generators), including Midwest Generation. These developments included lower prices and greater volatility in wholesale energy markets in the United States, significant declines in the credit ratings of most major market participants, decreased availability of debt financing or refinancing, and a resulting decline of liquidity in the energy markets due to growing concern about the ability of counterparties to perform their obligations. Since the beginning of 2003, several merchant generators have reached agreements to extend existing bank credit facilities and at least three merchant generators have filed for Chapter 11 protection under the United States Bankruptcy Code.

On October 28, 2003, Standard & Poor's Ratings Service downgraded the credit rating of Midwest Generation's parent, Edison Mission Midwest Holdings (syndicated loan facility to B from BB-). Standard & Poor's also lowered the credit ratings on Midwest Generation's indirect parent, EME (senior unsecured debt to B from BB-), on Edison Mission Marketing & Trading (corporate credit rating to B from BB-), on the pass-through certificates related to the sale-leaseback of the Powerton and Joliet stations (to B from BB-), and on the senior secured bank facility related to the sale-leaseback of the Collins Station (to B from BB-). Standard & Poor's placed the ratings of all of these entities on CreditWatch with negative implications. These ratings actions did not trigger any defaults under Edison Mission Midwest Holdings' credit facilities or those of the other affected entities.

respectively. In the future, so long as the ratings remain at the current level or lower, amounts of excess cash flow deposited in the cash flow recapture account at the end of each calendar quarter will be used upon deposit to prepay, pro rata, amounts then outstanding under these bank facilities. There was no change to the cost of borrowings for Edison Mission Midwest Holdings as a result of the downgrade. The Edison Mission Midwest Holdings $781 million of debt maturing on December 11, 2003, of which Midwest Generation is the guarantor, will need to be repaid, extended or refinanced. Edison Mission Midwest Holdings does not have sufficient cash to repay this indebtedness when due.

On November 13, 2003, EME's subsidiary, Mission Energy Holdings International, Inc. received a commitment letter from Citigroup, Credit Suisse First Boston, JPMorganChaseBank and Lehman Brothers Inc. to provide a three-year, $700 million secured loan intended to provide bridge financing to asset sales, including the sale of some or all of its international operations, depending upon, among other things, market prices. Subject to completion, the net proceeds from this financing will be used to make an equity contribution of approximately $550 million in Edison Mission Midwest Holdings which, together with cash on hand, will be used to repay Edison Mission Midwest Holdings' $781 million indebtedness due on December 11, 2003. Funding of this loan is subject to completion of definitive documentation and a number of closing conditions, including obtaining certain consents and required corporate authorizations by EME and Mission Energy Holding Company. Completion of this loan is subject to uncertainty and, accordingly, there is no assurance that definitive documentation will be completed and the closing conditions will be fulfilled.

A failure to repay, extend or refinance the Edison Mission Midwest Holdings $781 million obligation is likely to result in a default under the Mission Energy Holding Company senior secured notes and term loan. These events could make it necessary for Midwest Generation to file a petition for reorganization under Chapter 11 of the United States Bankruptcy Code. Midwest Generation's independent accountants' audit opinion for the year ended December 31, 2002 contains an explanatory paragraph that indicates the financial statements have been prepared on the basis that Midwest Generation will continue as a going concern and that the uncertainty about Edison Mission Midwest Holdings' ability to repay, extend or refinance this obligation raises substantial doubt about Midwest Generation's ability to continue as a going concern. Accordingly, the financial statements do not include any adjustments that might result from the resolution of this uncertainty.

During the second quarter of 2003, Midwest Generation recorded an asset impairment charge of $1.025 billion ($625 million after tax) that resulted from a revised long-term outlook for capacity revenues from the Collins Station and eight small peaking plants. The lower capacity revenue outlook was the result of a number of factors, including higher long-term natural gas prices and the current oversupply of generation in the MAIN region market. The book value of capitalized assets related to the Collins Station was written down from $858 million to an estimated fair market value of $78 million, and the book value of the eight small peaking plants was written down from $286 million to an estimated fair market value of $41 million. The estimated fair value was determined based on discounting estimated future pretax cash flows using a 17.5% discount rate.

During the third quarter of 2002, Midwest Generation recorded an asset impairment charge of $25.4 million related to the write-off of capitalized costs associated with the suspension of capital improvements at its Powerton Station.

Statement of Financial Accounting Standards No. 143. Effective January 1, 2003, Midwest Generation adopted Statement of Financial Accounting Standards No. 143, "Accounting for Asset Retirement Obligations." SFAS No. 143 requires entities to record the fair value of a liability for a legal asset retirement obligation in the period in which it is incurred. When the liability is initially recorded, the entity capitalizes the cost by increasing the carrying amount of the related long-lived asset. Over time, the liability is increased to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. Upon settlement of the liability, an entity either settles the obligation for its recorded amount or incurs a gain or loss upon settlement. The adoption of SFAS No. 143 did not have a material impact on Midwest Generation's financial statements ($74 thousand, after tax, decrease to net income as the cumulative effect of adoption of SFAS No. 143).

Statement of Financial Accounting Standards No. 146. Effective January 1, 2003, Midwest Generation adopted Statement of Financial Accounting Standards No. 146, "Accounting for Costs Associated with Exit or Disposal Activities." SFAS No. 146 requires that liabilities for costs associated with exit or disposal activities initiated after December 31, 2002 be recognized when incurred, rather than at the date of a commitment to an exit or disposal plan. The adoption of this standard had no impact on Midwest Generation's financial statements.

Statement of Financial Accounting Standards No. 149. In April 2003, the Financial Accounting Standards Board (FASB) issued Statement of Financial Accounting Standards No. 149, "Amendment of Statement 133 on Derivative Instruments and Hedging Activities." This statement amends and clarifies financial accounting and reporting for derivative instruments and for hedging activities under SFAS No. 133. The amendment reflects decisions made by the FASB and the Derivatives Implementation Group (DIG) process in connection with issues raised about the application of SFAS No. 133. Generally, the provisions of SFAS No. 149 will be applied prospectively for contracts entered into or modified after June 30, 2003 and for hedging relationships designated after June 30, 2003. SFAS No. 149 provisions that resulted from the DIG process that became effective in fiscal quarters beginning before June 15, 2003 will continue to be applied based upon their original effective dates. The adoption of this standard had no impact on Midwest Generation's financial statements.

Statement of Financial Accounting Standards Interpretation No. 45. In November 2002, the FASB issued Statement of Financial Accounting Standards Interpretation No. 45, "Guarantor's Accounting and Disclosure Requirements for Guarantees, Including Indirect Guarantees of Indebtedness of Others." This interpretation establishes reporting requirements to be made by a guarantor about its obligations under certain guarantees that it has issued. It also clarifies that a guarantor is required to recognize, at the inception of a guarantee, a liability for the fair value of the obligation undertaken in issuing the guarantee. The initial recognition and initial measurement provisions of this interpretation are applicable on a prospective basis to guarantees issued or modified after December 31, 2002. The adoption of this standard had no impact on Midwest Generation's financial statements. See disclosure regarding guarantees and indemnities in Note 5—Commitments and Contingencies.

Emerging Issues Task Force No. 03-11. In July 2003, the EITF reached a consensus on Issue No. 03-11, "Reporting Realized Gains and Losses on Derivative Instruments that are Subject to FASB Statement No. 133, Accounting for Derivative Instruments and Hedging Activities, and Not Held for Trading Purposes." EITF Issue No. 03-11 provides guidance on whether realized gains and losses on derivative contracts should be reported on a net or gross basis and concludes such classification is a matter of judgment that depends on the relevant facts and circumstances. In analyzing the facts and

circumstances, EITF Issue No. 99-19, "Reporting Revenue Gross as a Principal Versus Net as an Agent," should be considered. Gains and losses on non-trading derivative instruments are recognized in income (loss) from price risk management in the accompanying statements of operations. The consensus is effective prospectively for Midwest Generation's transactions or arrangements entered into or modified after September 30, 2003.

Statement of Financial Accounting Standards Interpretation No. 46. In January 2003, the FASB issued Statement of Financial Accounting Standards Interpretation No. 46, "Consolidation of Variable Interest Entities." This interpretation of Accounting Research Bulletin No. 51, "Consolidated Financial Statements," addresses consolidation by business enterprises of variable interest entities. The primary objective of the interpretation is to provide guidance on the identification of, and financial reporting for, entities over which control is achieved through means other than voting rights; such entities are known as variable interest entities. This interpretation applies to variable interest entities created after January 31, 2003, and applies to variable interest entities in which Midwest Generation holds a variable interest that it acquired before February 1, 2003. Effective October 9, 2003, the FASB issued Statement of Financial Accounting Standards Interpretation No. 46-6, "Effective Date of Financial Accounting Standards Interpretation No. 46, Consolidation of Variable Interest Entities." This interpretation delays the effective date for applying the provisions of FIN 46 to variable interest entities in which Midwest Generation holds a variable interest that it acquired before February 1, 2003 until the end of the first interim or annual period ended after December 15, 2003. Midwest Generation does not expect that this standard will have a material impact on its financial statements.

	Unrealized Gains (Losses) on Cash Flow Hedges			Accumulated Other Comprehensive Income (Loss)
Balance at December 31, 2002	$	(999	)	$	(999	)
Current period change		18,473			18,473

Balance at September 30, 2003	$	17,474		$	17,474

Unrealized gains on cash flow hedges at September 30, 2003 include forward energy sales contracts that did not meet the normal sales and purchases exception under SFAS No. 133. These gains arise because current forecasts of future electricity prices are lower than Midwest Generation's contract prices. As Midwest Generation's hedged positions are realized, approximately $11.0 million, after tax, of the net unrealized gains on cash flow hedges will be reclassified into earnings during the next twelve months. Management expects that when the hedged items are recognized in earnings, the net unrealized gains associated with them will be offset. Actual amounts ultimately reclassified to earnings over the next twelve months could vary materially from this estimated amount as a result of changes in market conditions. The maximum period over which a cash flow hedge is designated is through July 31, 2005.

Under SFAS No. 133, the portion of a cash flow hedge that does not offset the change in value of the transaction being hedged, which is commonly referred to as the ineffective portion, is immediately recognized in earnings. Midwest Generation recorded net losses of $4.8 million and $1.0 million during the third quarter and nine months ended September 30, 2003, respectively, representing the amount of cash flow hedges' ineffectiveness, reflected in income (loss) from price risk management in the statement of operations.

The following table summarizes Midwest Generation's commercial commitments as of September 30, 2003.

Electric power generated at Midwest Generation's power generation plants has historically been sold under three power purchase agreements with Exelon Generation, in which Exelon Generation purchases capacity and has the right to purchase energy generated by the power generation plants. Midwest Generation initially entered into agreements with Commonwealth Edison on December 15, 1999, and they were subsequently assigned to Exelon Generation in January 2001. The power purchase agreements, which expire in December 2004, provide for capacity and energy payments. Exelon Generation is obligated to make capacity payments for the power generation plants under contract and energy payments for the electricity produced by these plants and taken by Exelon Generation. The capacity payments provide the power generation plants revenue for fixed charges, and the energy payments compensate the power generation plants for all, or a portion of, variable costs of production.

Under each of the power purchase agreements, Exelon Generation, upon notice by given dates, has had the option to terminate each agreement with respect to all or a portion of the units subject to it. As a result of notices given in 2002, effective January 1, 2003, Exelon Generation released 4,548 MW of Midwest Generation's generating capacity from the power purchase agreements, thus increasing Midwest Generation's reliance on sales into the wholesale markets. As a result, 4,739 MW of capacity remain subject to power purchase agreements with Exelon Generation in 2003.

Exelon Generation notified Midwest Generation on June 25, 2003 of the exercise of its option to contract 687 MW of capacity and the associated energy output (out of a possible total of 1,265 MW subject to the option) during 2004 from Midwest Generation's coal-fired units in accordance with the terms of the existing power purchase agreement related to Midwest Generation's coal-fired generation units. As a result, 578 MW of the capacity of these units will no longer be subject to the power purchase agreement beginning January 1, 2004. The notification received from Exelon Generation has no effect on its commitments to purchase capacity from these generating units for the balance of 2003. For 2004, Exelon Generation will have 2,383 MW of capacity related to its coal-fired generation units under contract with Midwest Generation.

On October 1, 2003, Exelon Generation notified Midwest Generation of the exercise of its option to retain under a power purchase agreement for calendar year 2004 the 1,084 MW of capacity and energy from Midwest Generation's Collins Station currently under contract for calendar year 2003. Exelon Generation also exercised its option to release from a related power purchase agreement 302 MW of capacity and energy (out of a possible total of 694 MW subject to the option) from Midwest Generation's natural gas and oil-fired peaking units, thereby retaining under that contract 392 MW of the capacity and energy of such units for calendar year 2004. The notification received from Exelon Generation has no effect on its commitments to purchase capacity from these peaking units for the balance of 2003.

As a result of notices given in 2003, as described above, effective January 1, 2004, Exelon Generation released an additional 880 MW of generating capacity, leaving 3,859 MW of capacity remaining subject to the power purchase agreements with Exelon Generation in 2004.

When Exelon Generation does not fully dispatch the power generation plants under contract, Midwest Generation may sell, subject to specified conditions, the excess energy at market prices to neighboring utilities, municipal utilities, third-party electric retailers and power marketers on a spot basis. A bilateral trading infrastructure already exists with access to the Mid-America Interconnected Network and the East Central Area Reliability Council.

In February 2003, Midwest Generation entered into an amendment to a fuel supply agreement with one of its coal suppliers and Commonwealth Edison, under an agency agreement that was part of the initial acquisition of the Illinois Plants. The amendment provides for fixed payments, in lieu of the prior fuel purchase obligations, of $7 million for 2003, $7 million for 2004, $7 million for 2005, $8 million for 2006, $8 million for 2007 and $40 million thereafter. Midwest Generation adjusted the liability recorded as part of the purchase of the Illinois Plants for this above market fuel supply contract to the net present value of the fixed payments and recorded a gain of $2 million during the first quarter of 2003.

Midwest Generation has entered into additional fuel purchase agreements with several third-party suppliers during the first nine months of 2003. Midwest Generation's aggregate fuel purchase commitments under these agreements are currently estimated to be $39 million for 2003, $199 million for 2004, $195 million for 2005, $89 million for 2006 and $91 million for 2007.

Midwest Generation is subject to environmental regulation by federal, state and local authorities in the United States. Midwest Generation believes that it is in substantial compliance with environmental regulatory requirements and that maintaining compliance with current requirements will not materially affect its financial position or results of operations. However, possible future developments, such as the promulgation of more stringent environmental laws and regulations, and future proceedings which may be taken by environmental authorities, could affect the costs and the manner in which Midwest Generation conducts its business and could cause Midwest Generation to make substantial additional capital expenditures. There is no assurance that Midwest Generation would be able to recover these increased costs from its customers or that its financial position and results of operations would not be materially adversely affected.

Typically, environmental laws require a lengthy and complex process for obtaining licenses, permits and approvals prior to construction and operation of a new project or modification of an existing project. Meeting all the necessary requirements can delay or sometimes prevent the completion of a proposed project as well as require extensive modifications to existing projects, which may involve significant capital expenditures. If Midwest Generation fails to comply with applicable environmental laws, it may be subject to penalties and fines imposed by regulatory authorities.

Midwest Generation has entered into interconnection agreements with Commonwealth Edison to provide interconnection services necessary to connect the Illinois Plants with its transmission systems. Unless terminated earlier in accordance with the terms thereof, the interconnection agreements will terminate on a date mutually agreed to by both parties. This date may not exceed the retirement date of the Illinois Plants. Midwest Generation is required to compensate Commonwealth Edison for all reasonable costs associated with any modifications, additions or replacements made to the interconnection facilities or transmission systems in connection with any modification, addition or upgrade to the Illinois Plants.

Midwest Generation has guaranteed Edison Mission Midwest Holdings' third-party debt in the amount of $1.7 billion at September 30, 2003. Midwest Generation's parent also pledged the membership interests in Midwest Generation to the lenders in connection with the third-party debt arrangements. Midwest Generation has not recorded a liability related to this guarantee.

In connection with the sale-leaseback transactions related to the Collins Station and the Powerton and Joliet Stations, EME, Midwest Generation and another wholly owned subsidiary of EME entered into tax indemnity agreements. Under these tax indemnity agreements, these entities agreed to indemnify the lessors in the sale-leaseback transactions for specified adverse tax consequences that could result in certain situations set forth in each tax indemnity agreement, including specified defaults under the respective leases. The potential indemnity obligation under these tax indemnity agreements could be significant. Due to the nature of these obligations under these tax indemnity agreements, Midwest Generation cannot determine a maximum potential liability. The indemnities would be triggered by a valid claim from the lessors. Midwest Generation has not recorded a liability related to these indemnities.

Midwest Generation entered into a supplemental agreement with Commonwealth Edison on February 20, 2003 to resolve a dispute regarding interpretation of its reimbursement obligation for asbestos claims under the environmental indemnities set forth in the Asset Sale Agreement dated March 22, 1999. Under this supplemental agreement, Midwest Generation agreed to reimburse Commonwealth Edison 50% of specific existing asbestos claims less recovery of insurance costs, and agreed to a sharing arrangement for liabilities associated with future asbestos related claims as specified in the agreement. The obligations under this agreement are not subject to a maximum liability. The supplemental agreement has a five-year term with an automatic renewal provision (subject to the right to terminate). Payments are made under this indemnity by a valid claim provided from Commonwealth Edison. At September 30, 2003, Midwest Generation had $5.9 million recorded as a liability related to known claims provided by Commonwealth Edison and had made $1.2 million in payments.

	Nine Months Ended September 30,
	2003			2002
Cash paid for interest	$	275,988	*	$	313,550
Cash paid for income taxes	$	—		$	—

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS

The following discussion contains forward-looking statements. These statements are based on Midwest Generation, LLC's (Midwest Generation's) knowledge of present facts, current expectations about future events and assumptions about future developments. Forward-looking statements are not guarantees of performance; they are subject to risks, uncertainties and assumptions that could cause actual future activities and results of operations to be materially different from those set forth in this discussion. Important factors that could cause actual results to differ include risks set forth under "—Market Risk Exposures" below, and under "—Risk Factors" in the Management's Discussion and Analysis of Results of Operations and Financial Condition included in Item 7 of Midwest Generation's annual report on Form 10-K for the year ended December 31, 2002. References in this quarterly report to Midwest Generation's annual report on Form 10-K for the year ended December 31, 2002 include the Amendment No. 1 on Form 10-K/A filed on May 6, 2003.

The Management's Discussion and Analysis of Financial Condition and Results of Operations of this Form 10-Q discusses material changes in the results of operations, financial condition and other developments of Midwest Generation since December 31, 2002, and as compared to the third quarter and nine months ended September 30, 2002. This discussion presumes that the reader has read or has access to the Management's Discussion and Analysis of Results of Operations and Financial Condition included in Item 7 of Midwest Generation's annual report on Form 10-K for the year ended December 31, 2002.

Midwest Generation is a special-purpose Delaware limited liability company formed on July 12, 1999 for the purpose of owning or leasing, making improvements to and operating the power generation assets it purchased from Commonwealth Edison, which are referred to as the Illinois Plants. Midwest Generation is a wholly owned subsidiary of Edison Mission Midwest Holdings Co., an indirect wholly owned subsidiary of Edison Mission Energy, which is referred to as EME. EME is a wholly owned subsidiary of Mission Energy Holding Company and is an indirect wholly owned subsidiary of Edison International.

In connection with the acquisition of the Illinois Plants, Midwest Generation entered into three five-year power purchase agreements for the coal-fired stations, the Collins Station, and the peaker stations, with Commonwealth Edison, that expire in December 2004. Subsequently, Commonwealth Edison assigned its rights and obligations under these power purchase agreements to its affiliate, Exelon Generation. Midwest Generation has entered into a contract with a marketing affiliate to market energy that is to be sold into the wholesale market as permitted under the power purchase agreements, to engage in hedging activities and to provide scheduling and other services. The marketing affiliate also purchases fuel, other than coal, and enters into fuel hedging arrangements on Midwest Generation's behalf.

Under the terms of the power purchase agreements with Exelon Generation, Midwest Generation receives significantly higher capacity payments during June through September, the summer months. In addition, due to higher electricity demand resulting from warmer weather during the summer months, energy revenues are substantially higher during the third quarter. Accordingly, Midwest Generation's operating results are substantially higher during these months and lower, including expected losses, during non-summer months.

including Midwest Generation. These developments included lower prices and greater volatility in wholesale energy markets in the United States, significant declines in the credit ratings of most major market participants, decreased availability of debt financing or refinancing, and a resulting decline of liquidity in the energy markets due to growing concern about the ability of counterparties to perform their obligations. Since the beginning of 2003, several merchant generators have reached agreements to extend existing bank credit facilities and at least three merchant generators have filed for Chapter 11 protection under the United States Bankruptcy Code.

As a result of the October 28, 2003 Standard & Poor's downgrade of Edison Mission Midwest Holdings to B from BB-, the cash on deposit in the cash flow recapture account ($245.9 million) related to Edison Mission Midwest Holdings' indebtedness was required to be used to prepay that indebtedness, with the amount of such prepayment applied ratably to the $911 million and $808.3 million tranches thereof. Therefore, on October 29, 2003, $130.3 million from the cash flow recapture account was applied to the $911 million tranche and $115.6 million was applied to the $808.3 million tranche, thereby reducing the debt obligations to $780.7 million and $692.7 million, respectively. In the future, so long as the ratings remain at the current level or lower, amounts of excess cash flow deposited in the cash flow recapture account at the end of each calendar quarter will be used upon deposit to prepay, pro rata, amounts then outstanding under these bank facilities. There was no change to the cost of borrowings for Edison Mission Midwest Holdings as a result of the downgrade. The Edison Mission Midwest Holdings $781 million of debt maturing on December 11, 2003, of which Midwest Generation is the guarantor, will need to be repaid, extended or refinanced. Edison Mission Midwest Holdings does not have sufficient cash to repay this indebtedness when due.

Generation will continue as a going concern and that the uncertainty about Edison Mission Midwest Holdings' ability to repay, extend or refinance this obligation raises substantial doubt about Midwest Generation's ability to continue as a going concern. Accordingly, the financial statements do not include any adjustments that might result from the resolution of this uncertainty.

The table below depicts operating statistics related to coal-fired generation, which represents the majority of Midwest Generation's operations, and Midwest Generation's total capacity revenues.

			Three Months Ended September 30,						Nine Months Ended September 30,
			2003			2002			2003			2002
Statistics—Coal-Fired Generation
	Generation (in GWhr):
		Power purchase agreement		3,806			8,345			10,481			20,392
		Merchant		4,195			137			10,073			493

		Total coal-fired generation		8,001			8,482			20,554			20,885

	Availability(1)			95.6	%		94.1	%		83.9	%		84.4	%
	Forced outage rate(2)			4.4	%		5.9	%		6.6	%		6.2	%
	Average realized energy price/MWh:
		Power purchase agreement	$	18.06		$	16.76		$	18.22		$	16.77
		Merchant	$	28.92		$	22.66		$	26.79		$	20.93

		Total coal-fired generation	$	23.76		$	16.85		$	22.42		$	16.87

Capacity revenues (in millions)			$	222		$	345		$	348		$	546

Operating revenues decreased $104.9 million and $109.4 million for the third quarter and nine months ended September 30, 2003, respectively, compared to the corresponding periods of 2002. The third quarter decline was primarily due to an approximately $123 million decrease in capacity revenue resulting from the reduction in megawatts contracted under the power purchase agreements with Exelon Generation as described below, partially offset by an approximately $24 million increase in energy revenue due to the shift to merchant generation. The shift to merchant generation has resulted in minimal capacity revenues but higher energy revenues due to higher average realized energy prices as compared to energy prices set forth in the power purchase agreements with Exelon Generation. The nine-month period decline was due to an approximately $198 million decrease in capacity revenue resulting from the reduction in megawatts contracted under the power purchase agreements with Exelon Generation, partially offset by an approximately $89 million increase in energy revenue due to the shift to merchant generation.

In accordance with the power purchase agreements, Exelon Generation released 4,548 MW of Midwest Generation's generating capacity during 2002 from the power purchase agreements. Of the generating capacity released by Exelon Generation, Midwest Generation suspended operations for 1,370 MW and decommissioned 45 MW. As a result, beginning in 2003, Midwest Generation has had 3,133 MW of uncontracted capacity available for sale in the merchant generation market.

Exelon Generation is obligated under the power purchase agreements to make capacity payments for the plants under contract (4,739 MW during 2003) and energy payments for electricity produced by these plants. As a result of the decline in contracted generating capacity under the power purchase agreements, revenues from Exelon Generation as a percentage of Midwest Generation's total energy and capacity revenues decreased from 99% for the third quarter of 2002 to 73% for the third quarter of 2003 and from 99% for the first nine months of 2002 to 71% for the first nine months of 2003. For more information on the power purchase agreements and wholesale energy markets, see "—Market Risk Exposures."

Losses from price risk management were $6.0 million and none for the third quarter and $2.3 million and $2.2 million for the nine months ended September 30, 2003 and 2002, respectively. The 2003 losses primarily represent the ineffective portion of Midwest Generation's forward energy sales contracts which are derivatives that qualified as cash flow hedges under SFAS No. 133. The ineffectiveness losses were attributable to differences in energy prices between "Into ComEd" and delivery points outside "Into ComEd." Also included in the 2003 losses is a mark-to-market adjustment of an option Midwest Generation has to purchase energy from Calumet Energy Team LLC, which is accounted for as a derivative under SFAS No. 133. The 2002 losses represent the change in market value of futures contracts with respect to a portion of anticipated fuel purchases that did not qualify as cash flow hedges under SFAS No. 133.

Operating expenses (excluding asset impairment charges) decreased $26.9 million and $9.9 million in the third quarter and nine months ended September 30, 2003, respectively, compared to the corresponding periods of 2002. Operating expenses consist of expenses for fuel, plant operations, depreciation and amortization and administrative and general expenses. The change in the components of operating expenses is discussed below.

Fuel expenses decreased $27.4 million and $4.5 million in the third quarter and nine months ended September 30, 2003, respectively, compared to the corresponding periods of 2002. The third quarter decrease was primarily due to lower generation at the Collins Station as well as the coal stations. The nine-month period decrease was primarily due to lower overall generation.

Plant operations expenses increased $6.0 million and decreased $10.2 million in the third quarter and nine months ended September 30, 2003, respectively, compared to the corresponding periods of 2002. The third quarter increase was primarily due to higher plant maintenance. The nine-month period decrease was primarily due to lower labor costs resulting from cost reductions implemented in the fourth quarter of 2002, lower employee benefit costs and the elimination of rent expense on the Illinois peaker power units lease due to the termination of the lease in August 2002.

Depreciation and amortization expense decreased $6.4 million and increased $5.3 million in the third quarter and nine months ended September 30, 2003, respectively, compared to the corresponding periods of 2002. The third quarter decrease is due to the elimination of depreciation and amortization on the portion of the Collins Station and eight peaking plants that were impaired in June 2003. The nine-month period increase was primarily due to the $300 million purchase of the Illinois peaker power units in August 2002 that were previously subject to a lease, in addition to other recurring capital expenditure additions. Depreciation expense primarily relates to the acquisition of the Illinois Plants which are being depreciated over periods ranging from 20 to 40 years and the Illinois peaker power units which are being depreciated over 15 years, effective August 2002. The amortization expense relates to the Powerton-Joliet facilities sale-leaseback and the Collins Station sale-leaseback which are being amortized over the term of the leases.

Asset impairment charges for the nine months ended September 30, 2003 consisted of a $1.025 billion ($625 million after tax) impairment charge during June 2003 that resulted from a revised

long-term outlook for capacity revenues from the Collins Station and eight small peaking plants. The lower capacity revenue outlook is the result of a number of factors, including higher long-term natural gas prices and the current oversupply of generation in the MAIN region market. The book value of capitalized assets related to the Collins Station was written down from $858 million to an estimated fair market value of $78 million, and the book value of the eight small peaking plants was written down from $286 million to an estimated fair market value of $41 million. The estimated fair value was determined based on discounting estimated future pretax cash flows using a 17.5% discount rate.

		Three Months Ended September 30,						Nine Months Ended September 30,
		2003			2002			2003			2002
		(in thousands)
Interest income and other expense		$	(321	)	$	(184	)	$	(630	)	$	(488	)
Interest income from affiliate			28,333			29,388			85,022			90,524
Interest expense			(30,826	)		(29,122	)		(93,078	)		(86,406	)
Interest expense to affiliate			(55,262	)		(57,047	)		(165,149	)		(168,198	)

	Total other expense	$	(58,076	)	$	(56,965	)	$	(173,835	)	$	(164,568	)

Interest income from affiliate decreased $1.1 million and $5.5 million in the third quarter and nine months ended September 30, 2003, respectively, compared to the corresponding periods of 2002. The third quarter and nine-month period decreases were due to the repayment received from EME in August 2002 on the $300 million note in connection with Midwest Generation's purchase of the peaker power units.

Interest expense related to the lease financings of the Collins, Powerton and Joliet Stations increased $1.7 million and $6.7 million in the third quarter and nine months ended September 30, 2003, respectively, compared to the corresponding periods of 2002. The third quarter and nine-month period increases were primarily the result of credit rating downgrades in 2002 which increased the index applicable to the variable component of the Collins lease financing.

Interest expense to affiliate decreased $1.8 million and $3.0 million in the third quarter and nine months ended September 30, 2003, respectively, compared to the corresponding periods of 2002. Interest expense to affiliate relates to borrowings from Edison Mission Overseas Co., a wholly owned subsidiary of Midwest Generation's parent, under subordinated loan agreements. The third quarter and nine-month period decreases were due to lower debt balances on the subordinated revolving line of credit, partially offset by higher interest costs on the variable rate subordinated loan agreement.

Midwest Generation had effective income tax rates of (39.0)% and 43.6% in the first nine months of 2003 and 2002, respectively. The effective income tax rates were different from the federal statutory rate of 35% due to state income taxes. The income tax benefit results from the tax-allocation agreement with Midwest Generation's parent, Edison Mission Midwest Holdings.

Effective January 1, 2003, Midwest Generation adopted Statement of Financial Accounting Standards No. 143, "Accounting for Asset Retirement Obligations." SFAS No. 143 requires entities to record the fair value of a liability for a legal asset retirement obligation in the period in which it is incurred. When the liability is initially recorded, the entity capitalizes the cost by increasing the carrying

amount of the related long-lived asset. Over time, the liability is increased to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. Upon settlement of the liability, an entity either settles the obligation for its recorded amount or incurs a gain or loss upon settlement. On January 1, 2003, Midwest Generation recorded a $74 thousand, after tax, decrease to net income as the cumulative effect of adoption of SFAS No. 143.

Net loss was $642.3 million in the nine months ended September 30, 2003, compared to a net income of $31.4 million for the corresponding period of 2002. The 2003 loss was primarily due to the Collins Station and small peaking plants impairment charges recorded in the second quarter of 2003. See "—Results of Operations—Operating Expenses" for additional discussion. Although Midwest Generation expects to generate cash flow from operations, it expects to incur annual losses after depreciation, amortization and interest expense for several years. Midwest Generation's future results of operations will depend primarily on revenues from the sale of energy, capacity and other related products, and the level of its operating expenses.

At September 30, 2003, Midwest Generation had cash and cash equivalents of $245.1 million compared to $74.7 million at December 31, 2002. Net working capital was $(585.6) million at September 30, 2003 compared to $(853.3) million at December 31, 2002. The negative working capital is primarily the result of the classification of $911 million of debt as a current liability due in December 2003. The decrease in negative working capital is primarily the result of increased cash and accounts receivable balances due to the seasonal nature of the business.

Net cash provided by operating activities decreased $43.0 million in the first nine months of 2003 compared to the corresponding period of 2002. The decrease in cash provided by operating activities was primarily due to lower operating income in 2003 and due to the timing of cash receipts and disbursements relating to working capital items.

Net cash provided by financing activities was $171.6 million in the first nine months of 2003 compared to net cash used in financing activities of $8.9 million in the corresponding period of 2002. In 2003, Midwest Generation borrowed approximately $181 million on its subordinated revolving line of credit with affiliate primarily to pay for interest owed on both affiliate loans. In 2002, Midwest Generation had negligible net borrowings on its affiliate loans.

Net cash used in investing activities decreased $15.8 million in the first nine months of 2003 compared to the corresponding period of 2002. The net decrease was primarily due to lower capital expenditures.

Midwest Generation plans to spend approximately $10 million on capital expenditures for the remainder of 2003. These capital expenditures are planned to be financed by cash generated from operations. Midwest Generation's principal source of liquidity is cash on hand and future cash flow from operations. In addition, Midwest Generation has access to a $150 million working capital facility through its parent, which is scheduled to expire on December 15, 2004.

As a result of the downgrade of the credit rating of Edison Mission Midwest Holdings by Standard & Poor's (see "—Credit Ratings of Edison Mission Midwest Holdings"), Midwest Generation repaid $245.9 million on October 29, 2003 under its subordinated loan agreement with its affiliate, Edison Mission Overseas (which mirrors the Edison Mission Midwest Holdings' credit agreements with

commercial lenders), through a borrowing under its subordinated revolving line of credit, also with Edison Mission Overseas. The following table summarizes Midwest Generation's debt maturities to its affiliate (in millions):

		At September 30, 2003		October Settlement			Balance After Settlement		Due Date
Subordinated Loan Agreement
	Tranche A	$	911.0	$	(130.3	)	$	780.7	December 11, 2003
	Tranche B		808.3		(115.6	)		692.7	December 15, 2004
Subordinated Revolving Loan Agreement			1,875.6		245.9			2,121.5	December 15, 2034

Total Subordinated Debt		$	3,594.9	$	—		$	3,594.9

Midwest Generation plans to repay, extend or refinance Tranche A of its subordinated loan agreements as part of Edison Mission Midwest Holdings' plan to repay, extend or refinance its $781 million debt obligation (guaranteed by Midwest Generation) prior to its maturity on December 11, 2003. Edison Mission Midwest Holdings does not have sufficient cash to repay this indebtedness when due.

Midwest Generation's parent company, Edison Mission Midwest Holdings, is the borrower under a $1.869 billion credit facility with a group of commercial banks. Midwest Generation has guaranteed its parent company's obligations under this credit facility. The funds borrowed under this facility were used to fund Midwest Generation's original acquisition and provide working capital to its operations. As part of the original acquisition, Midwest Generation entered into a sale-leaseback transaction for the Collins Station, which Edison Mission Midwest Holdings guarantees, and then subsequently entered into sale-leaseback transactions for the Powerton Station and the Joliet Station in August 2000. In order for Edison Mission Midwest Holdings to make a distribution, Edison Mission Midwest Holdings and Midwest Generation must be in compliance with the covenants specified in these agreements, including maintaining a minimum credit rating. Because the credit rating of Edison Mission Midwest Holdings is below investment grade, no distributions can currently be made by Edison Mission Midwest Holdings to its parent company, and ultimately to EME, at this time.

Edison Mission Midwest Holdings must maintain a debt service coverage ratio for the prior twelve-month period of at least 1.50 to 1 as long as the power purchase agreements with Exelon Generation represent 50% or more of Edison Mission Midwest Holdings' and its subsidiaries' revenues. If the power purchase agreements with Exelon Generation represent less than 50% of Edison Mission

Midwest Holdings' and its subsidiaries' revenues, it must maintain a debt service coverage ratio of at least 1.75 to 1. Midwest Generation expects that revenues for 2003 from Exelon Generation will represent 50% or more of its revenues. In addition, Edison Mission Midwest Holdings must maintain a debt-to-capital ratio no greater than 0.60 to 1. Failure to meet the historical debt service coverage ratio and the debt-to-capital ratio are events of default under the credit agreement and Collins lease agreements, which, upon a vote by a majority of the lenders could cause an acceleration of the due date of the obligations of Edison Mission Midwest Holdings and those associated with the Collins lease. Such an acceleration could result in an event of default under the Powerton and Joliet leases. During the 12 months ended September 30, 2003, the historical debt service coverage ratio was 2.31 to 1 and the debt-to-capital ratio was 0.52 to 1.

There are no restrictions on the ability of Midwest Generation to make payments on the outstanding intercompany loans from its affiliate, Edison Mission Overseas (which is also a subsidiary of Edison Mission Midwest Holdings) or to make distributions directly to Edison Mission Midwest Holdings.

Credit ratings for EME, Edison Mission Midwest Holdings and Edison Mission Marketing & Trading are as follows:

	Moody's Rating	S&P Rating
Edison Mission Energy	B2	B
Edison Mission Midwest Holdings	Ba3	B
Edison Mission Marketing & Trading	Not Rated	B

On October 28, 2003, Standard & Poor's Ratings Service downgraded the credit rating of Midwest Generation's parent, Edison Mission Midwest Holdings (syndicated loan facility to B from BB-). Standard & Poor's also lowered the credit ratings on Midwest Generation's indirect parent, EME (senior unsecured debt to B from BB-), on Edison Mission Marketing & Trading (corporate credit rating to B from BB-), on the pass-through certificates related to the sale-leaseback of the Powerton and Joliet stations (to B from BB-), and on the senior secured bank facility related to the sale-leaseback of the Collins Station (to B from BB-). Standard & Poor's placed the ratings of all of these entities on CreditWatch with negative implications. Moody's Investors Service has assigned a negative rating outlook for EME and Edison Mission Midwest Holdings.

These ratings actions did not trigger any defaults under Edison Mission Midwest Holdings' credit facilities or those of the other affected entities. See "Credit Ratings of Edison Mission Midwest Holdings" for further discussion of the impact of the ratings action on Edison Mission Midwest Holdings.

Midwest Generation cannot provide assurance that the credit ratings above will remain in effect for any given period of time or that one or more of these ratings will not be lowered further. Midwest Generation notes that these credit ratings are not recommendations to buy, sell or hold securities and may be revised at any time by a rating agency.

Credit Ratings of Edison Mission Energy and Edison Mission Marketing & Trading

Midwest Generation sells merchant energy and capacity and purchases its natural gas and fuel oil through its marketing affiliate, Edison Mission Marketing & Trading, which currently has a below investment grade credit rating. In order to support Midwest Generation's forward sales and hedging, EME (which also has a below investment grade credit rating) provided collateral in the form of cash and letters of credit for the benefit of Edison Mission Marketing & Trading's counterparties. As of October 31, 2003, EME had provided $40 million in collateral to support Edison Mission Marketing & Trading's operations including the forward sales and hedging activities related to Midwest Generation. Midwest Generation anticipates that sales of its power through Edison Mission Marketing & Trading may require additional credit support, depending upon market conditions and the strategies adopted for the sale of this power. Changes in forward market prices and margining requirements could further increase the need for credit support related to price risk management activities. Without an investment grade credit rating, EME's ability to provide credit support may be limited. Midwest Generation may provide collateral to support bilateral contracts for power and fuel to the extent that any such transactions relate to Midwest Generation's merchant energy operations. Depending on market conditions and the volume and duration of forward sales, there is no assurance that EME and Midwest Generation will be able to provide credit support to Edison Mission Marketing & Trading.

As a result of Edison Mission Midwest Holdings' credit rating being below investment grade since October 2002, provisions in the agreements binding on Edison Mission Midwest Holdings required it to deposit, on a quarterly basis, 100% of its excess cash flow as defined in the agreements into a cash flow recapture account held and maintained by the collateral agent. In accordance with these provisions, Edison Mission Midwest Holdings deposited $78 million into the cash flow recapture account as of September 30, 2003. In October 2003, Edison Mission Midwest Holdings deposited an additional $168 million based on the calculation of excess cash flow for the third quarter ended September 30, 2003. The funds in the cash flow recapture account were to be used only to meet debt service obligations of Edison Mission Midwest Holdings, which Midwest Generation has guaranteed, if funds were not otherwise available from working capital. The deposit of funds into this account limited the amount of funds that would otherwise be available by Edison Mission Midwest Holdings to lend to Midwest Generation to meet working capital requirements.

As part of the sale-leaseback of the Powerton and Joliet Stations, Midwest Generation loaned the proceeds (in the amount of $1.367 billion) to EME in exchange for promissory notes in the same aggregate amount. Debt service payments by EME on the promissory notes may be used by Midwest Generation to meet its payment obligations under these leases in whole or part. Furthermore, EME has guaranteed Midwest Generation's lease obligations under these leases. EME's obligations under the promissory notes payable to Midwest Generation are general corporate obligations of EME and are not

contingent upon receiving distributions from its subsidiaries. Accordingly, EME is still obligated to continue to make payments under the intercompany loans from Midwest Generation, notwithstanding EME's inability to receive distributions from Edison Mission Midwest Holdings because Edison Mission Midwest Holdings' credit rating is below investment grade. Since Edison Mission Midwest Holdings is restricted from making distributions to EME, EME needs to generate sufficient cash flow from other subsidiaries or sources in excess of its interest and overhead costs to continue to make payments under the intercompany loans from Midwest Generation. There is no assurance that EME will have sufficient cash flow to meet these obligations. If Midwest Generation does not receive payment on the intercompany loans from EME, Midwest Generation would not be able to meet its lease obligations under the Powerton and Joliet leases due to restrictions under the credit agreement of Edison Mission Midwest Holdings and the Powerton and Joliet leases. If EME also failed to pay under its guarantee, this would result in an event of default under the Powerton and Joliet leases and may lead to default under the Collins lease and credit agreement of Edison Mission Midwest Holdings, which Midwest Generation has guaranteed. These events would have a material adverse effect on Midwest Generation.

In April 2003, Midwest Generation and Commonwealth Edison amended their February 2003 settlement agreement which terminated Midwest Generation's obligation to build additional gas-fired generation in the Chicago area. In accordance with the amendment, Midwest Generation paid Commonwealth Edison $9.8 million in exchange for the termination of nine annual installment payments of $1.5 million beginning in 2004 and for the termination of the security interest of Commonwealth Edison in 125,000 barrels of oil at the Collins Station.

Midwest Generation's primary market risk exposures arise from fluctuations in electricity and fuel prices, emission allowances, transmission rights and interest rates. Midwest Generation manages these risks in part by using derivative financial instruments in accordance with established policies and procedures. See "—Current Developments" and "—Credit Ratings" for a discussion of market developments and their impact on Midwest Generation's credit and the credit of its counterparties.

Midwest Generation's merchant power plants expose it to commodity price risk, which represents the potential loss that can be caused by a change in the market value of a particular commodity.

Commodity price risks are actively monitored to ensure compliance with Midwest Generation's risk management policies through its marketing affiliate. Policies are in place which define the risk tolerance for Midwest Generation. Procedures exist which allow for monitoring of all commitments and positions with regular reviews by a risk management committee. Midwest Generation's marketing affiliate performs a "value at risk" analysis in its daily business to measure, monitor and control Midwest Generation's overall market risk exposure. The use of value at risk allows management to aggregate overall commodity risk, compare risk on a consistent basis and identify the drivers of the risk. Value at risk measures the possible loss over a given time interval, under normal market conditions, at a given confidence level. Given the inherent limitations of value at risk and relying on a single risk measurement tool, Midwest Generation's marketing affiliate supplements this approach with the use of stress testing and worst-case scenario analysis, as well as stop loss limits and counterparty credit exposure limits. Despite this, there can be no assurance that all risks have been accurately identified, measured and/or mitigated.

As discussed further below, beginning in 2003, Midwest Generation has been selling a significant portion of its energy into wholesale energy markets. Midwest Generation enters into forward contracts for a portion of its electric output that is not committed to be sold under the power purchase agreements with Exelon Generation in order to provide more predictable earnings and cash flow. When appropriate, Midwest Generation manages the spread between electric prices and fuel prices, and uses forward contracts, swaps, futures, or options contracts to achieve those objectives. There is no assurance that contracts to hedge changes in market prices will be effective.

With the exception of revenue generated by the three power purchase agreements with Exelon Generation, Midwest Generation's revenues and results of operations will depend upon prevailing market prices for capacity, energy, ancillary services, emission allowances, fuel oil, coal, natural gas and associated transportation costs in the market area known as the MAIN Region and neighboring markets. Among the factors that influence the price of power in the MAIN Region are:

Midwest Generation's reliance on sales into the wholesale markets. As a result, 4,739 MW of capacity remain subject to power purchase agreements with Exelon Generation in 2003.

Under the Collins Station power purchase agreement, Exelon Generation has the right to purchase all of the energy associated with unreleased capacity produced by the Collins Station. Energy prices vary depending on the total annual number of megawatt-hours of energy purchased and the market price of natural gas. When purchases exceed an annual threshold of 2.7 million MWh, prorated to 1.085 million MWh in 2003 due to the release of units, Exelon Generation purchases energy at market prices and thus bears all subsequent risk of changes in the market price of natural gas and fuel oil used to produce the energy purchased. The Collins Station is capable of burning fuel oil in lieu of natural gas, which enables Midwest Generation to use fuel oil when it costs less than natural gas. Midwest Generation has in the past purchased and has in inventory stocks of fuel oil for this purpose.

The energy and capacity from any units which are not subject to one of the power purchase agreements with Exelon Generation are sold under terms, including price and quantity, negotiated by Midwest Generation's marketing affiliate with customers through a combination of bilateral agreements, forward energy sales and spot market sales. These arrangements generally have a term of two years or less. Thus, Midwest Generation is subject to the market risks related to the price of energy and capacity described above. Midwest Generation expects that capacity prices for merchant energy sales will, in the near term, be negligible in comparison to those Midwest Generation currently receives under its existing agreements with Exelon Generation (the possibility of minimal revenues is due to the current oversupply conditions in this marketplace). Midwest Generation further expects that the lower revenues resulting from this difference will be offset in part by energy prices, which Midwest Generation believes will, in the near term, be higher for merchant energy sales than those Midwest Generation currently receives under its existing agreements, as indicated below in the table of forward-looking prices. Midwest Generation intends to manage this price risk, in part, by accessing both the wholesale customer and over-the-counter markets described below as well as using derivative financial instruments in accordance with established policies and procedures.

During 2003 and 2004, the primary markets available to Midwest Generation for wholesale sales of electricity are expected to be "wholesale customer" and "over-the-counter." The most liquid over-the-counter markets in the Midwest region are sales into the control area of Cinergy, referred to as "Into Cinergy," and, to a lesser extent, sales into the control area of Commonwealth Edison, referred to as "Into ComEd" (due to geographic proximity, "Into ComEd" has been the primary market for Midwest Generation). "Into Cinergy" and "Into ComEd" are bilateral markets for the sale or purchase of electrical energy for future delivery. Performance of transactions in these markets is subject to contracts that generally provide for liquidated damages supported by a variety of credit requirements, which may include independent credit assessment, parent company guarantees, letters of credit and cash margining arrangements.

The following table depicts the historical average market prices for energy per megawatt-hour "Into ComEd" and "Into Cinergy" for the first nine months of 2003:

The following table sets forth forward market prices for energy per megawatt-hour as quoted for sales "Into ComEd" and "Into Cinergy" at September 30, 2003. These forward prices will continue to fluctuate as a result of a number of factors, including gas prices, electricity demand, which is also affected by economic growth, and the amount of existing and planned power plant capacity. The actual spot prices for electricity delivered into these markets may vary materially from the forward market prices.

Midwest Generation intends to hedge a portion of its merchant portfolio risk through its marketing affiliate. To the extent it does not do so, the unhedged portion will be subject to the risks and benefits of spot market price movements. The extent to which Midwest Generation will hedge its market price risk through forward over-the-counter sales depends on several factors. First, Midwest Generation will evaluate over-the-counter market prices to determine whether sales at forward market prices are sufficiently attractive compared to assuming the risk associated with spot market sales. Second, Midwest Generation's ability to enter into hedging transactions will depend upon its and its marketing affiliate's credit capacity and upon the over-the-counter forward sales markets' having sufficient liquidity to enable Midwest Generation to identify counterparties who are able and willing to enter into hedging transactions with it. Due to factors beyond Midwest Generation's control, market liquidity has decreased significantly since the beginning of 2002 and a number of formerly significant trading parties have completely withdrawn from the market or substantially reduced their trading activities. See "—Credit Risk," below.

In addition to the prevailing market prices, Midwest Generation's ability to derive profits from the sale of electricity from the released units will be affected by the cost of production, including costs incurred to comply with environmental regulations. The costs of production of the released units vary and, accordingly, depending on market conditions, the amount of generation that will be sold from the released units is expected to vary from unit to unit. In this regard, Midwest Generation suspended operations of Will County Units 1 and 2 and Collins Station Units 4 and 5 at the end of 2002 pending improvement in market conditions. If market conditions were to be depressed for an extended period of time, Midwest Generation would need to consider decommissioning Will County Units 1 and 2, which would result in a charge against income. Collins Station Units 4 and 5 are subject to a long-term lease which requires that for the term of the lease, these units be maintained in condition for return to service, should market conditions improve. Thus, in the absence of an agreement with the lessor under the lease, Midwest Generation cannot decommission these units.

In addition to the price risks described previously, Midwest Generation's ability to transmit energy to counterparty delivery points to consummate spot sales and hedging transactions may also be affected by transmission service limitations and constraints and new standard market design proposals proposed by and currently pending before the Federal Energy Regulatory Commission, or the FERC. Although the FERC and the relevant industry participants are working to minimize such issues, Midwest Generation cannot determine how quickly or how effectively such issues will be resolved. Currently, transmission must be obtained from Commonwealth Edison under its open-access tariff filed with the FERC. Such transmission procurement is expected to continue throughout 2003. There is considerable uncertainty about Commonwealth Edison's integration in PJM. For further details see "—Regulatory Matters." Midwest Generation is unable to predict the outcome of these efforts or the effect of any final integration configuration on the markets into which Midwest Generation sells its power.

The following table summarizes the fair values for outstanding financial instruments used for price risk management activities by instrument type. The substantial change in fair value of electricity contracts is attributable to the decline in average market prices to below contracted prices during September, which is the valuation date, causing the fair value of the contracts to become assets instead of liabilities.

In assessing the fair value of its derivative financial instruments, Midwest Generation uses a variety of methods and assumptions based on the market conditions and associated risks existing at each balance sheet date. The fair value of commodity price contracts takes into account quoted market prices, time value of money, volatility of the underlying commodities and other factors. The following table summarizes the maturities, the valuation method and the related fair value of Midwest Generation's commodity risk management assets and liabilities as of September 30, 2003 (in thousands):

		Total Fair Value			Maturity <1 year			Maturity 1 to 3 years			Maturity 4 to 5 years			Maturity >5 years
Prices actively quoted		$	28,661		$	18,482		$	10,179		$	—		$	—

As a result of Exelon Generation's notification to release some of Midwest Generation's units from the respective power purchase agreements in 2003 and 2004, Midwest Generation is selling a significant portion of its energy into wholesale energy markets and intends to hedge its merchant portfolio risk through its marketing affiliate.

In conducting price risk management activities, Midwest Generation's marketing affiliate enters into contracts with a number of utilities, energy companies and financial institutions. Due to factors beyond Midwest Generation's control, market liquidity has decreased significantly since the beginning of 2002, and a number of formerly significant trading parties have completely withdrawn from the market or substantially reduced their trading activities. The reduction in the credit quality of traditional trading parties increases Midwest Generation's credit risk. In addition, the decrease in market liquidity may require Midwest Generation to rely more heavily on wholesale electricity sales to wholesale customer markets which may also increase its credit risk. While various industry groups and regulatory agencies have taken steps to address market liquidity, transparency and credit issues, there is no assurance as to when or how effectively such efforts will restore market confidence. In the event a counterparty were to default on its trade obligation, Midwest Generation would be exposed to the risk of possible loss associated with reselling the contracted product at a lower price if the non-performing counterparty were unable to pay the resulting liquidated damages owed to Midwest Generation. Further, Midwest Generation would be exposed to the risk of non-payment of accounts receivable accrued for products delivered prior to the time such counterparty defaulted.

To manage credit risk, Midwest Generation's marketing affiliate looks at the risk of a potential default by its counterparties. Credit risk is measured by the loss that Midwest Generation would record if its counterparties failed to perform pursuant to the terms of their contractual obligations. Midwest Generation's marketing affiliate has established controls to determine and monitor the creditworthiness of counterparties and uses master netting agreements whenever possible to mitigate its exposure to counterparty risk. This may require counterparties to pledge collateral when deemed necessary. Midwest Generation's marketing affiliate tries to manage the credit in its portfolio based on credit ratings using published ratings of counterparties and other publicly disclosed information, such as financial statements, regulatory filings, and press releases to guide it in the process of setting credit levels, risk limits and contractual arrangements, including master netting agreements. The credit quality of Midwest Generation's marketing affiliate's counterparties is reviewed regularly by a risk management committee. In addition to continuously monitoring Midwest Generation's credit exposure to its counterparties, Midwest Generation's marketing affiliate also takes appropriate steps to limit or lower credit exposure. Despite this, there can be no assurance that Midwest Generation's marketing affiliate's actions to mitigate risk will be wholly successful or that collateral pledged will be adequate.

Interest rate changes affect the cost of borrowings needed to operate the facilities and Midwest Generation's lease costs under the Collins Station lease.

For a discussion of Midwest Generation's regulatory matters, refer to "Regulatory Matters" on page 14 of Midwest Generation's annual report on Form 10-K for the year ended December 31, 2002 and the notes to the Financial Statements set forth in the Amendment No. 1 on Form 10-K/A. There have been no significant developments with regard to regulatory matters that affect disclosures presented in the annual report, except as follows:

Currently, power produced by Midwest Generation not under contract with Exelon Generation is sold using transmission which must be obtained from Commonwealth Edison under its open-access tariff filed with the FERC. In 2002, Commonwealth Edison applied to the FERC for approval to join PJM in conjunction with American Electric Power, thereby creating an enlarged, contiguous regional transmission organization encompassing a broad regional market. Approval of this application was granted by the FERC on April 1, 2003. Concurrently, the ability of American Electric Power to join PJM has been brought into question by the enactment of legislation in Virginia requiring the approval of Virginia state authorities for any transfer of control from American Electric Power to PJM of American Electric Power transmission assets located in Virginia. On April 16, 2003, Commonwealth Edison and PJM issued a joint press release stating that the integration of Commonwealth Edison into PJM would proceed separately from that of American Electric Power, notwithstanding the absence of a direct transmission link owned by Commonwealth Edison between its service territory and the existing PJM. In response to this announcement, EME, Midwest Generation, and other affected parties filed with the FERC for clarification or rehearing of its April 1, 2003 order, and essentially contested the appropriateness of Commonwealth Edison joining PJM on an "islanded" basis. The FERC has clarified that a series of pre-conditions imposed by an order issued on July 31, 2002, tentatively approving the stated decisions of Commonwealth Edison and American Electric Power to join PJM together continue to be applicable to the separate application of Commonwealth Edison to join PJM standing alone. Those conditions include (a) the elimination of multiple transmission rates between PJM and the Midwest Independent System Operator (Midwest ISO), which controls the transmission markets surrounding the service territory of Commonwealth Edison, and (b) an agreement between PJM and the Midwest ISO regarding the management of operations across their "seams," which are required to be done in such a manner as to hold harmless utility customers of the Midwest ISO in Wisconsin and Michigan from the adverse effects of congestion and loop flows caused by the membership of Commonwealth Edison in PJM. On August 1, 2003, Commonwealth Edison filed a notice of appeal of the July 31, 2002 order and the June 4, 2003 order on rehearing with the U.S. Court of Appeals for the D.C. Circuit.

On August 20, 2003, PJM issued a press release announcing the delay of Commonwealth Edison's integration in PJM which was previously planned for November 1, 2003. PJM intends to review the events surrounding the August 14, 2003 blackout to ensure that the Joint Operating Agreement and associated reliability plan with the Midwest ISO will enhance the reliability performance. As the investigation proceeds, PJM will determine a revised schedule for Commonwealth Edison's market integration in PJM. Such integration is not expected to take place during 2003.

On July 23, 2003, the FERC issued an order finding that the regional through and out rates (RTORs) of the Midwest ISO and PJM are unjust and unreasonable when applied to transactions sinking within the proposed Midwest ISO/PJM footprint and directed Midwest ISO and PJM to make a compliance filing within thirty days eliminating the RTORs. The FERC also initiated an investigation and hearing to determine whether the through and out rate under the tariffs of individual former

Alliance Companies are unjust, unreasonable or unduly discriminatory or preferential for transactions sinking in the proposed Midwest ISO/PJM footprint. On October 14, 2003, the FERC issued an order extending the effective date for the elimination of Midwest ISO and PJM RTORs. The new deadline for the elimination of such rates will be set in the order on rehearing, which the FERC intends to issue in the near future.

On September 29 and 30, 2003, the FERC held a hearing and inquiry into regional transmission organization issues related to the Midwest ISO and PJM. The purpose of the inquiry was to gather sufficient information to move forward in resolving the commitment made by several entities, including Commonwealth Edison, to establish a joint and common market in the Midwest and PJM region. The inquiry explored the impediments to the former Alliance Companies' participation in either the Midwest ISO or PJM. See also "Market Risk Exposures—Commodity Price Risk."

For a discussion of Midwest Generation's off-balance sheet transactions, refer to "Off-Balance Sheet Transactions" on page 41 of Midwest Generation's annual report on Form 10-K for the fiscal year ended December 31, 2002.

For a discussion of Midwest Generation's environmental matters, refer to "Environmental Matters and Regulations" on page 51 of Midwest Generation's annual report on Form 10-K for the fiscal year ended December 31, 2002 and the notes to the Financial Statements set forth in the Amendment No. 1 on Form 10-K/A. There have been no other significant developments with regard to environmental matters that affect disclosures presented in the annual report, except as follows.

On February 21, 2003, Midwest Generation received a request for information under Section 114 of the Clean Air Act regarding past operations, maintenance and physical changes at its coal plants from the United States Environmental Protection Agency, or EPA. This request was part of the EPA's industry-wide investigation of compliance by coal-fired plants with the Clean Air Act new source review, or NSR, requirements. On July 28, 2003, Commonwealth Edison received a substantially similar request for information from the EPA related to these same plants. Other than these requests for information, no enforcement-related proceedings have been initiated by the EPA with respect to Midwest Generation's facilities.

A federal district court, ruling on a lawsuit filed by the EPA, found on August 7, 2003 that the Ohio Edison Company violated requirements of the NSR program within the Clean Air Act by upgrading certain coal-fired power plants without first obtaining the necessary preconstruction permits. On August 26, 2003, another federal district court, ruling in an NSR enforcement action against Duke Energy Corporation, adopted a different interpretation of the NSR provisions that could limit liability for similar upgrade projects.

In addition, however, the EPA, on October 27, 2003, issued its final rule (effective December 26, 2003) revising its regulations to define more clearly a category of activities that are not subject to NSR requirements under the "routine maintenance, repair and replacement" exclusion. This regulation may mitigate some or all of the potential impact of the Ohio Edison decision, particularly as to future repair and replacement projects.

Both recent judicial decisions and the newly issued regulation are currently under review by Midwest Generation to assess what implications, if any, they will have on the operation of its power plants or on its results of operations or financial position.

For a discussion of Midwest Generation's critical accounting policies and estimates, refer to "Critical Accounting Policies and Estimates" on page 32 of Midwest Generation's annual report on Form 10-K for the fiscal year ended December 31, 2002.

Statement of Financial Accounting Standards No. 149. In April 2003, the FASB issued Statement of Financial Accounting Standards No. 149, "Amendment of Statement 133 on Derivative Instruments and Hedging Activities." This statement amends and clarifies financial accounting and reporting for derivative instruments and for hedging activities under SFAS No. 133. The amendment reflects decisions made by the FASB and the Derivatives Implementation Group (DIG) process in connection with issues raised about the application of SFAS No. 133. Generally, the provisions of SFAS No. 149 will be applied prospectively for contracts entered into or modified after June 30, 2003 and for hedging relationships designated after June 30, 2003. SFAS No. 149 provisions that resulted from the DIG process that became effective in fiscal quarters beginning before June 15, 2003 will continue to be applied based upon their original effective dates. The adoption of this standard had no impact on Midwest Generation's financial statements.

Emerging Issues Task Force No. 03-11. In July 2003, the EITF reached a consensus on Issue No. 03-11, "Reporting Realized Gains and Losses on Derivative Instruments that are Subject to FASB

Statement No. 133, Accounting for Derivative Instruments and Hedging Activities, and Not Held for Trading Purposes." EITF Issue No. 03-11 provides guidance on whether realized gains and losses on derivative contracts should be reported on a net or gross basis and concludes such classification is a matter of judgment that depends on the relevant facts and circumstances. In analyzing the facts and circumstances, EITF Issue No. 99-19, "Reporting Revenue Gross as a Principal Versus Net as an Agent," should be considered. Gains and losses on non-trading derivative instruments are recognized in income (loss) from price risk management in the accompanying statements of operations. The consensus is effective prospectively for Midwest Generation's transactions or arrangements entered into or modified after September 30, 2003.

For a discussion of market risk sensitive instruments, refer to "Market Risk Exposures" on page 42 in Item 7 of Midwest Generation's annual report on Form 10-K for the fiscal year ended December 31, 2002. Refer to "Market Risk Exposures" in Item 2 for an update to that disclosure.

Midwest Generation's management, with the participation of the company's Chief Executive Officer and Chief Financial Officer, has evaluated the effectiveness of Midwest Generation's disclosure controls and procedures (as such term is defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (the "Exchange Act")) as of the end of the period covered by this report. Based on such evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that, as of the end of such period, Midwest Generation's disclosure controls and procedures are effective.

There have not been any changes in Midwest Generation's internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) during the fiscal quarter to which this report relates that have materially affected, or are reasonably likely to materially affect, Midwest Generation's internal control over financial reporting.

Exhibit No.		Description
31.1		Certification of the Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act.
31.2		Certification of the Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act.
32		Statement Pursuant to 18 U.S.C. Section 1350.

Date of Report		Dated Filed		Item(s) Reported
August 5, 2003		August 5, 2003		5, 12*

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 thereunto duly authorized.

(Mark One)
ý	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the Quarterly Period Ended September 30, 2003
or
o	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Delaware		33-0868558
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)
One Financial Place 440 South LaSalle Street, Suite 3500 Chicago, Illinois		60605
(Address of principal executive offices)		(Zip Code)

			Three Months Ended September 30,						Nine Months Ended September 30,
			2003			2002			2003			2002
Operating Revenues
	Energy revenues		$	87,224		$	181,733		$	241,243		$	417,010
	Capacity revenues			221,998			344,654			348,183			546,051
	Energy and capacity revenues from marketing affiliate			121,346			3,103			274,606			10,317
	Loss from price risk management			(6,013	)		—			(2,332	)		(2,242	)

		Total operating revenues		424,555			529,490			861,700			971,136

Operating Expenses
	Fuel			119,560			146,951			315,257			319,719
	Plant operations			76,050			70,082			248,141			258,330
	Asset impairment charges			—			25,402			1,025,333			25,402
	Depreciation and amortization			38,431			44,828			133,743			128,411
	Administrative and general			6,772			5,868			18,428			18,981

		Total operating expenses		240,813			293,131			1,740,902			750,843

Operating income (loss)				183,742			236,359			(879,202	)		220,293

Other Income (Expense)
	Interest income and other			28,012			29,204			84,392			90,036
	Interest expense			(86,088	)		(86,169	)		(258,227	)		(254,604	)

		Total other expense		(58,076	)		(56,965	)		(173,835	)		(164,568	)

Income (loss) before income taxes and accounting change				125,666			179,394			(1,053,037	)		55,725
Provision (benefit) for income taxes				48,448			67,643			(410,785	)		24,318

Income (Loss) Before Accounting Change				77,218			111,751			(642,252	)		31,407
	Cumulative effect of change in accounting, net of tax (Note 3)			—			—			(74	)		—

Net Income (Loss)			$	77,218		$	111,751		$	(642,326	)	$	31,407

			Three Months Ended September 30,					Nine Months Ended September 30,
			2003		2002			2003			2002
Net Income (Loss)			$	77,218	$	111,751		$	(642,326	)	$	31,407
Other comprehensive income (expense), net of tax:
	Unrealized gains (losses) on derivatives qualified as cash flow hedges:
		Other unrealized holding gains (losses) arising during period, net of income tax expense (benefit) of $12,295 and $(225) for the three months and $(403) and $(121) for the nine months ended September 30, 2003 and 2002, respectively		19,203		(319	)		(630	)		(172	)
		Reclassification adjustments included in net income (loss), net of income tax benefit of $2,202 and $12,232 for the three months and nine months ended September 30, 2003, respectively		3,438		—			19,103			—

Other comprehensive income (expense)				22,641		(319	)		18,473			(172	)

Comprehensive Income (Loss)			$	99,859	$	111,432		$	(623,853	)	$	31,235

			September 30, 2003		December 31, 2002
Assets
Current Assets
	Cash and cash equivalents		$	245,123	$	74,652
	Accounts receivable, net of allowance of $4,269 in 2002			94,563		61,090
	Due from affiliates			33,184		6,603
	Fuel inventory			62,856		79,293
	Spare parts inventory			19,335		18,636
	Interest receivable from affiliate			28,018		56,395
	Assets under price risk management			29,279		2,312
	Other current assets			14,643		26,844

		Total current assets		527,001		325,825

Property, Plant and Equipment				4,185,202		5,285,234
	Less accumulated depreciation			506,492		480,097

		Net property, plant and equipment		3,678,710		4,805,137

Notes receivable from affiliate				1,365,423		1,366,502
Deferred taxes				320,480		—
Other assets				4,964		3,155

Total Assets			$	5,896,578	$	6,500,619

			September 30, 2003			December 31, 2002
Liabilities and Member's Equity
Current Liabilities
	Accounts payable		$	11,775		$	32,333
	Accrued liabilities			64,747			90,975
	Due to affiliates			3,467			3,444
	Interest payable			66,489			88,051
	Interest payable to affiliates			44,328			40,545
	Liabilities under price risk management			618			2,959
	Current maturities of subordinated long-term debt with affiliate			911,000			911,000
	Current portion of lease financing			10,214			9,792

		Total current liabilities		1,112,638			1,179,099

Subordinated revolving line of credit with affiliate				1,875,648			1,694,282
Subordinated long-term debt with affiliate, net of current maturities				808,308			808,308
Lease financing, net of current portion				2,159,641			2,169,855
Deferred taxes				—			73,354
Benefit plans and other long-term liabilities				98,672			118,430

Total Liabilities				6,054,907			6,043,328

Commitments and Contingencies (Note 5)
Member's Equity
	Membership interests, no par value; 100 units authorized, issued and outstanding			—			—
	Additional paid-in capital			688,748			680,515
	Accumulated deficit			(864,551	)		(222,225	)
	Accumulated other comprehensive loss			17,474			(999	)

Total Member's Equity				(158,329	)		457,291

Total Liabilities and Member's Equity			$	5,896,578		$	6,500,619

			Nine Months Ended September 30,
			2003			2002
Cash Flows From Operating Activities
	Net income (loss)		$	(642,326	)	$	31,407
	Adjustments to reconcile net income (loss) to net cash provided by operating activities:
		Depreciation and amortization		133,743			128,411
		Non-cash contribution of services		8,233			8,313
		Asset impairment charges		1,025,333			25,402
		Deferred taxes		(393,788	)		28,851
		Cumulative effect of change in accounting, net of tax		74			—
	Increase in accounts receivable			(33,473	)		(101,623	)
	(Increase) decrease in due from affiliates			(26,558	)		4,943
	Decrease in inventory			15,738			8,364
	Decrease in interest receivable from affiliate			28,377			30,845
	(Increase) decrease in other current assets			12,201			(3,157	)
	Decrease in accounts payable			(20,558	)		(6,716	)
	Decrease in accrued liabilities			(26,228	)		(8,802	)
	Increase (decrease) in interest payable			(17,779	)		(58,946	)
	Decrease in other liabilities			(19,458	)		(3,352	)
	Increase in net assets under price risk management			(10,835	)		(8,280	)

		Net cash provided by operating activities		32,696			75,660

Cash Flows From Financing Activities
	Borrowings from subordinated long-term debt with affiliate			—			60,000
	Repayments of subordinated long-term debt with affiliate			—			(60,000	)
	Borrowings from subordinated revolving line of credit with affiliate			181,366			59,200
	Repayments of subordinated revolving line of credit with affiliate			—			(58,886	)
	Repayment of capital lease obligation			(9,792	)		(9,173	)

		Net cash provided by (used in) financing activities		171,574			(8,859	)

Cash Flows From Investing Activities
	Capital expenditures			(32,728	)		(350,122	)
	Increase in restricted cash			(2,150	)		—
	Repayment of loan from affiliate			1,079			300,498

		Net cash used in investing activities		(33,799	)		(49,624	)

Net increase in cash and cash equivalents				170,471			17,177
Cash and cash equivalents at beginning of period				74,652			52,635

Cash and cash equivalents at end of period			$	245,123		$	69,812

Commercial Commitments	2003		2004		2005		2006		2007		Thereafter		Total
	(in millions)
Capital improvements	$	7.3	$	4.6	$	—	$	—	$	—	$	—	$	11.9

	Into ComEd*						Into Cinergy*
Historical Energy Prices	Into ComEd*						Into Cinergy*
Historical Energy Prices	On-Peak(1)		Off-Peak(1)		24-Hr		On-Peak(1)		Off-Peak(1)		24-Hr
January	$	42.62	$	20.77	$	30.81	$	44.38	$	21.46	$	32.00
February		54.43		23.13		37.81		58.09		24.00		39.99
March		47.96		22.35		33.92		51.68		24.34		36.69
April		39.12		15.05		26.67		41.12		15.96		28.11
May		29.59		10.80		19.57		28.89		10.68		19.18
June		30.27		8.17		19.22		28.41		8.31		18.36
July		41.63		12.81		27.07		39.15		11.72		25.29
August		48.75		13.84		29.61		48.80		13.53		29.46
September		27.44		9.85		17.67		28.07		10.36		18.23

Nine-Month Average	$	40.20	$	15.20	$	26.93	$	40.95	$	15.60	$	27.48

		Into ComEd*						Into Cinergy*
Forward Energy Prices		Into ComEd*						Into Cinergy*
Forward Energy Prices		On-Peak(1)		Off-Peak(1)		24-Hr		On-Peak(1)		Off-Peak(1)		24-Hr
2003
	October	$	24.00	$	13.50	$	20.67	$	25.10	$	14.50	$	21.98
	November		27.30		16.50		21.06		29.87		17.00		22.43
	December		31.10		17.50		23.94		33.77		18.00		25.46
2004 Calendar "strip"(2)			33.64		15.95		24.24		35.95		18.10		26.46

		September 30, 2003		December 31, 2002
		(in thousands)
Commodity price:
	Electricity contracts	$	28,661	$	(647	)

		MIDWEST GENERATION, LLC (REGISTRANT)
		By:		/s/ Kevin M. Smith Kevin M. Smith Manager, Vice President and Treasurer
		Date:		November 14, 2003