Item 1. Business

We are an international energy company incorporated in Delaware on April 20, 1993. Our revenues are primarily generated through the production of electricity in the United States, the Philippines and the Caribbean. As of December 31, 2004, we owned or leased approximately 18,000 megawatts (“MW”) of electric generating capacity.

We manage our business through two principal operating segments: North America and International. Our North America segment consists of the ownership and operation of power generation facilities and energy trading and marketing operations. The International segment includes power generation businesses in the Philippines, Curacao and Trinidad and Tobago, and integrated utilities in the Bahamas and Jamaica. The table below summarizes selected 2004 financial information about our business segments.

	Revenues			%		Gross Margin		%		Operating Income (Loss)				Total Assets			Cash from Operating Activities
	($ in millions)
Business Segment:
North America		$	3,522	77	%	$	1,196	61	%		$	242		$	9,354			$	(168	)
International		1,050		23		756		39			(246		)	4,730				371
Corporate and Eliminations		—		—		—		—			(14		)	(2,660		)		(132		)
Total		$	4,572	100	%	$	1,952	100	%		$	(18	)	$	11,424			$	71

The annual, quarterly and current reports, and any amendments to those reports, that we file with or furnish to the SEC are available free of charge on our website at www.mirant.com as soon as reasonably practicable after they are electronically filed with or furnished to the SEC. General information about us, including our Corporate Governance Guidelines, the charters for our Audit, Compensation, and Nominating and Governance Committees, and our Code of Ethics and Business Conduct, can be found at www.mirant.com. We will provide print copies of these documents to any shareholder upon written request to Corporate Secretary, Mirant Corporation, 1155 Perimeter Center West, Atlanta, Georgia 30338. Information contained in our website is not incorporated into this Form 10-K.

As used in this report, “we,” “us,” “our,” the “Company” and “Mirant” refer to Mirant Corporation and its subsidiaries, unless the context requires otherwise.

Proceedings under Chapter 11 of the Bankruptcy Code

On July 14, 2003 and July 15, 2003 (collectively, the “Petition Date”), Mirant and 74 of its wholly-owned subsidiaries in the United States (collectively, the “Original Debtors”) filed voluntary petitions for relief under Chapter 11 in the Bankruptcy Court. On August 18, 2003, October 3, 2003 and November 18, 2003, four additional wholly-owned subsidiaries and four affiliates of Mirant commenced Chapter 11 cases under the Bankruptcy Code (together with the Original Debtors, the “Mirant Debtors”). The Chapter 11 cases of the Mirant Debtors are being jointly administered for procedural purposes only under the case caption In re Mirant Corporation et al., Case No. 03-46590 (DML).

Additionally, on the Petition Date, certain of our Canadian subsidiaries, Mirant Canada Energy Marketing, Ltd. and Mirant Canada Marketing Investments, Inc. (together, the “Mirant Canadian Subsidiaries”), filed an application for creditor protection under the Companies’ Creditors Arrangement Act in Canada (“CCAA”), which, like Chapter 11, allows for reorganization under the protection of the court system. The Mirant Canadian Subsidiaries emerged from creditor protection on May 21, 2004. The

accounting for their emergence is reflected in this report and did not have a material impact on our operating results.

Our businesses in the Philippines and the Caribbean were not included in the court-supervised reorganizations.

The Mirant Debtors are operating their businesses as debtors-in-possession under the jurisdiction of the Bankruptcy Court and in accordance with the applicable provisions of the Bankruptcy Code, the Federal Rules of Bankruptcy Procedure and applicable orders, as well as other applicable laws and rules. In general, each of the Mirant Debtors, as a debtor-in-possession, is authorized under the Bankruptcy Code to continue to operate as an ongoing business, but may not engage in transactions outside the ordinary course of business without the prior approval of the Bankruptcy Court.

The Office of the United States Trustee has established a committee of unsecured creditors for Mirant Corporation and a committee of unsecured creditors for Mirant Americas Generation, LLC (collectively, the “Creditor Committees”). The Office of the United States Trustee also has established a committee of equity security holders of Mirant Corporation (the “Equity Committee” and, collectively with the Creditor Committees, the “Statutory Committees”). Pursuant to an order of the Bankruptcy Court, the Office of the United States Trustee appointed an examiner (the “Examiner”) in these cases to analyze certain potential causes of action and to act as a mediator with respect to certain disputes that may arise among the Mirant Debtors, the Statutory Committees and other parties in interest.

Subject to certain exceptions in the Bankruptcy Code, the Chapter 11 filings automatically stayed the initiation or continuation of most actions against the Mirant Debtors, including most actions to collect pre-petition indebtedness or to exercise control over the property of the bankruptcy estates. As a result, absent an order of the Bankruptcy Court, creditors of the Mirant Debtors are precluded from collecting pre-petition debts and substantially all pre-petition liabilities are subject to compromise under a proposed plan or plans of reorganization in the bankruptcy proceedings. One exception to this stay of litigation is for an action or proceeding by a governmental agency to enforce its police or regulatory power.

On July 24, 2003, the Bankruptcy Court approved an interim procedure requiring certain direct and indirect holders of claims, preferred securities and common stock to provide at least ten days advance notice of their intent to buy or sell claims against the Mirant Debtors or shares in Mirant Corporation. The Bankruptcy Court entered a final order on September 17, 2003 and such order establishes notice procedures applicable only to those transactions with a person or entity owning (or, because of the transaction, resulting in ownership of) an aggregate amount of claims equal to or in excess of $250 million or such higher amount determined under the order and, with respect to shares, only those persons or entities owning (or, because of the transaction, resulting in ownership of) 4.75% or more of any class of outstanding shares. In addition, each entity or person that owns at least $250 million, or such higher amount determined under the order, of certain claims or preferred securities must provide Mirant and the Creditor Committees with notice of ownership information. The Court’s orders also provide for expedited procedures to impose sanctions for a violation of its orders, including monetary damages and, in some cases, the voidance of any such transactions that violate the order. Upon election, a special regime allowing virtually unlimited trading of claims without having to provide notice thereof may be available to certain claimholders, although such electing claimholders may be required to sell a portion of their claims before a specific date. The emergency and final relief was sought to prevent potential trades of claims of stock that could negatively impact the availability of the Mirant Debtors’ U.S. net operating loss carryforwards and other tax attributes. The U.S. federal net operating loss carryforward is approximately $2.8 billion at December 31, 2004. Even with the relief that has been granted, Mirant cannot guarantee that it will be able to benefit from all, or any portion, of its U.S. federal net operating loss carryforwards and other tax attributes. Similarly, there are approximately $3.9 billion of state net operating loss carryforwards. See “Critical Accounting Policies and Estimates” for further information.

Under the Bankruptcy Code, the Mirant Debtors also have the right to assume, assign, or reject certain executory contracts and unexpired leases, subject to the approval of the Bankruptcy Court and satisfaction of certain other conditions. The Mirant Debtors are continuing to evaluate their executory contracts in order to determine which contracts will be assumed, assigned or rejected.

In response to a motion filed under section 502(c) of the Bankruptcy Code (the “Estimation Motion”) by the Mirant Debtors, the Bankruptcy Court entered an order establishing procedures for estimating proofs of claim under section 502(c) of the Bankruptcy Code that are binding for all purposes, including voting on, feasibility of and distribution under a Chapter 11 plan for the Mirant Debtors. As a result, the Mirant Debtors filed approximately sixty material claim objections and three notices of intent to contest claims.

Plan of Reorganization

On January 19, 2005, the Mirant Debtors filed a proposed Plan of Reorganization and Disclosure Statement (the “Disclosure Statement”) with the Bankruptcy Court. The proposed Plan sets forth a proposed structure of the Company at emergence and how the claims of creditors and stockholders are to be treated. If the Disclosure Statement is found by the Bankruptcy Court to contain adequate information, then we will solicit votes on the proposed Plan from those creditors, security holders and interest holders who are entitled to vote on the proposed Plan.

The proposed Plan implements and includes the following key elements:

· the business of the Mirant Debtors will continue to be operated in substantially its current form, subject to certain internal structural changes that the Mirant Debtors believe will improve operational efficiency, facilitate and optimize their ability to meet financing requirements and accommodate the enterprise’s debt structure as contemplated at emergence;

· the original Mirant Debtors that are parties to the Chapter 11 proceedings, excluding Mirant Americas Generation, LLC (“Mirant Americas Generation”) and its subsidiaries (collectively, the “Mirant Americas Generation Debtors”), are substantively consolidated for all purposes under the proposed Plan;

· the Mirant Americas Generation Debtors are substantively consolidated for all purposes under the proposed Plan;

· the unsecured debt of the Mirant Americas Generation Debtors is to be paid in full through (i) the issuance to the lenders under the Mirant Americas Generation revolving credit facilities and the holders of Mirant Americas Generation senior notes maturing in 2006 and 2008 of (a) new debt securities of a newly formed intermediate holding company under Mirant Americas Generation (“New Mirant Americas Generation Holdco”) in an amount equal to 90% of the full amount owed to such creditors (as determined by the Bankruptcy Court) and (b) common stock in the new corporate parent of the Mirant Debtors (“New Mirant”) having a value equal to 10% of such amount owed; and (ii) the reinstatement of Mirant Americas Generation senior notes maturing in 2011, 2021 and 2031;

· to ensure the feasibility of the proposed Plan with respect to the Mirant Americas Generation Debtors and to resolve intercompany claims, the proposed Plan provides that additional value shall be contributed to Mirant Americas Generation, including the trading business (subject to an obligation to return a portion of the embedded capital in the trading business to Mirant), the Zeeland generating facility and commitments to make prospective capital contributions of up to $150 million (for refinancing) and $265 million (for sulfur dioxide capital expenditures);

· the prospective working capital requirements of Mirant Americas Generation will be met with the proceeds of a new first lien facility in the amount of at least $750 million;

· the bulk of the contingent liabilities of the Mirant Debtors associated with the California energy crisis and certain related matters will be resolved pursuant to a global settlement as described in “Item 3. Legal Proceedings” contained elsewhere in this report;

· substantially all of the assets of Mirant will be transferred to a new company to be formed pursuant to the proposed Plan, which will serve as the corporate parent of our business enterprise on and after the effective date of the proposed Plan and which shall have no successor liability for any unassumed obligations of Mirant Corporation, including any obligations to Potomac Electric Power Company (“PEPCO”) under the back-to-back agreement discussed under “Item 3. Legal Proceedings”; similarly, the trading business shall be transferred to Mirant Energy Trading, LLC, which shall have no successor liability for any unassumed obligations of Mirant Americas Energy Marketing, L.P. (“Mirant Americas Energy Marketing”), including any obligations to PEPCO under the back-to-back agreement discussed under “Item 3. Legal Proceedings” ; and

· the outstanding common stock in Mirant Corporation will be cancelled and the holders thereof will receive any surplus value after creditors are paid in full, plus the right to receive a pro rata share of warrants issued by New Mirant if they vote to accept the proposed Plan.

At present, the proposed Plan has not been approved by any of the Statutory Committees. As such, the Mirant Debtors anticipate that negotiations (which, whether or not successful, could lead to material changes to certain components of the proposed Plan) will continue between the Mirant Debtors and each of the Statutory Committees until the hearing to approve the adequacy of the Disclosure Statement. At present, the Bankruptcy Court has set the following schedule with respect to the Disclosure Statement: the First Amended Disclosure Statement is to be filed by March 25, 2005; objections to the draft Disclosure Statement are to be filed by April 1, 2005; the Second Amended Disclosure Statement is to be filed by April 15, 2005; and the Disclosure Statement adequacy hearing in the Bankruptcy Court is set for April 20, 2005.

At this time, it is not possible to accurately predict if or when the proposed Plan will be approved by the creditors and security holders and confirmed by the Bankruptcy Court, or if and when some or all of the Mirant Debtors may emerge from Bankruptcy Court protection under Chapter 11.

U.S. Competitive Environment

The power industry is one of the largest industries in the United States and has an influence on practically every aspect of the U.S. economy. Historically, the power generation industry in the United States was characterized by electric utility monopolies selling to franchised customer bases. In response to increasing customer demand for access to low-cost electricity and enhanced services, regulatory initiatives were adopted, primarily to increase wholesale and retail competition in the power industry. Following the resulting industry restructuring, merchant companies purchased plants from regulated utilities, built new capacity and began marketing to customers. At the same time, Independent System Operators (“ISOs”) and/or Regional Transmission Organizations (“RTOs”) were created to administer the new markets while maintaining system reliability. In recent years, state and federal restructuring efforts have stalled, primarily in response to the California energy crisis and financial troubles of many merchant energy companies. In addition, ISOs have begun exerting more control over market prices. The result is a blend of competitive and regulatory constructs, often different by state, under which merchant generators must compete with regulated utilities.

The substantial increase in new generation capacity that followed the restructuring of the U.S. power markets, utility capital investments to extend lives of older units, and the inability to decommission plants

for reliability reasons have created a prolonged oversupply situation. We do not expect our primary markets to reach target reserve margins, approximately 15% of excess capacity over peak demand, until 2008 to 2010. The market oversupply situation, price controls during periods of high demand or local constraint, and lack of appropriate compensation for locational capacity value currently limit fixed cost recovery for merchant generators.

With the expansion of the Pennsylvania-New Jersey-Maryland Interconnection, LLC (“ PJM”) market and the ongoing development of Midwest Independent System Operators (“MISO”), the markets themselves continue to evolve. This evolution has changed not only the utilization of generation and transmission resources, but also the voting interests among market participants.

Recently, natural gas has been the fuel of choice for new power generation facilities for economic, operational and environmental reasons. While this trend is expected to continue, some regulated utilities are now constructing clean coal units and renewable resources, often with subsidies or under legislative mandate. These utilities enjoy a lower cost of capital than most merchants and often are able to recover fixed costs through rate base mechanisms, allowing them to build, buy and upgrade generation without relying exclusively on market clearing prices to recover their investments.

Market liquidity stabilized or improved in most regions in 2004, as compared to 2003, allowing us to economically hedge portions of our expected electricity production up to 24 months in advance, primarily through exchange-traded contracts. However, market conditions, as well as conditions specific to us, have significantly reduced our marketing and risk management activities as compared to previous years.

Business Segments

For selected financial information about our business segments and information about geographic areas, see Note 20 to our consolidated financial statements contained elsewhere in this report. See “Item 2. Properties” for a complete list of our assets.

North America

Overview

In our North America segment, our core business is the production and sale of electrical energy, electrical capacity (essentially the ability to produce electricity on demand) and ancillary services. Our customers in the United States are utilities, municipal systems, aggregators, electric-cooperative utilities, producers, generators, marketers and large industrial customers. In the United States, we serve four primary geographic areas: (i) the Mid-Atlantic Region, (ii) the Northeast Region, (iii) the Mid-Continent Region, and (iv) the West Region.

Ownership and Operations of Electricity Generation Assets

As of December 31, 2004, we owned or leased generation facilities in the United States with an aggregate generation capacity of over 14,500 MW (including our Coyote Springs facility, the sale of which closed in January 2005, and our Wrightsville facility, which we expect to sell during 2005). Our domestic generating portfolio is diversified across fuel types, power markets and dispatch types and serves customers located near many major metropolitan load centers. Our total generation capacity included approximately 28% baseload units, 46% intermediate units and 26% peaking units. Mirant Americas Generation owns or controls approximately two-thirds of our U.S. generating capacity. We have six facilities in our North America business unit operating under long term contracted capacity contracts. At December 31, 2004, our contracted capacity was approximately 4,325 MW pursuant to agreements with terms expiring May 2005 through December 2014.

Commercial Operations

Our commercial operations, which are conducted through our Mirant Americas Energy Marketing subsidiary, consist of fuel procurement, power dispatch, logistics, asset hedging and risk management, and optimization trading. Mirant Americas Energy Marketing conducts its business in the markets in which we have an asset presence, which enhances our ability to deliver additional value as compared to only buying fuel and selling power in the spot market.

Pursuant to agreements with our subsidiaries that own generation facilities, Mirant Americas Energy Marketing enters into transactions for the benefit of such subsidiaries pursuant to which Mirant Americas Energy Marketing procures the appropriate fuel, formulates the daily dispatch decisions and sells the electricity generated in the wholesale market for the generation facilities. Mirant Americas Energy Marketing uses dispatch models to make daily decisions regarding the quantity and the price of the power it will sell into the markets. In most markets governed by ISOs/RTOs, Mirant Americas Energy Marketing bids the energy from our generation facilities into the ISO-run day-ahead energy market. Mirant Americas Energy Marketing also sells ancillary services through the ISO markets. In real-time, Mirant Americas Energy Marketing works with the ISOs/RTOs to ensure that our generation facilities are dispatched economically to meet the reliability needs of the market. In non-ISO markets, Mirant Americas Energy Marketing conducts business through bilateral transactions, on a day-ahead basis, pursuant to which Mirant Americas Energy Marketing provides the generation facilities with firm schedules to follow.

Mirant Americas Energy Marketing enters into contracts of varying terms to secure appropriate quantities of fuel that meet the varying specifications of our generating facilities. For our coal fired generation facilities, Mirant Americas Energy Marketing purchases coal from a variety of suppliers under both short-term and multi-year contracts. For our oil fired units, fuel is typically purchased under short-term contracts usually linked to a transparent oil index price. For our gas fired units, fuel is typically purchased under short-term contracts with a variety of suppliers.

Mirant Americas Energy Marketing enters into transactions to economically hedge our power price exposure by selling power into the wholesale market over a variety of tenors through over-the-counter transactions, exchanges and structured transactions. Mirant Americas Energy Marketing sells both energy and energy-linked commodities, including capacity and ancillary services. Mirant Americas Energy Marketing economically hedges the energy component of gross margin through futures, forwards, swaps and options. All of Mirant Americas Energy Marketing’s commercial activities are governed by our Risk Management Policy (“RMP”). The RMP requires that Mirant Americas Energy Marketing engage only in risk reducing activities with respect to hedging our assets.

While over-the-counter transactions make up a substantial portion of our economic hedge portfolio, Mirant Americas Energy Marketing also has a marketing function that serves as the interface between our generation facilities and customers. The marketing organization is focused on selling non-standard, structured products to customers. In addition to load following energy sales, these products typically include capacity, ancillary services, transmission losses and other energy products. Mirant Americas Energy Marketing views these transactions as a method of mitigating the risk of certain portions of our business that are not easy to economically hedge in the over-the-counter market. Typically, Mirant Americas Energy Marketing is able to sell these products at a higher premium than standard products. For certain generation facilities, Mirant Americas Energy Marketing has sought to enter into longer-term transactions to provide certainty of cash flows over an extended period. These transactions are typically tolling transactions whereby we receive a fixed capacity payment and, in return, grant an exclusive right for the counterparty to procure the fuel for the generation facility and take title to the power generated.

In addition to the risk management services that Mirant Americas Energy Marketing provides to our subsidiaries that own generation facilities, Mirant Americas Energy Marketing engages in optimization trading for its own account. Mirant Americas Energy Marketing generates gross margin by taking market

positions based, in part, on market and other information gathered from its relationship with our generation facilities. The optimization trading activities also are governed by the RMP, which sets forth limits on the size of trading positions and value-at-risk that Mirant Americas Energy Marketing can bear at any given time. By participating in the markets in this way, Mirant Americas Energy Marketing is better able to avoid disclosing to the markets the direction of its trading and hedging activity—to the benefit of our subsidiaries that own generation facilities. We also benefit from tighter bid/offer spreads because Mirant Americas Energy Marketing is active in the markets as both a buyer and seller.

Mid-Atlantic Region

We own, directly and indirectly, or lease four generation facilities comprising 5,256 MW of generation capacity in the Mid-Atlantic region: Chalk Point, Morgantown, Dickerson and Potomac River Station. Our Mid-Atlantic facilities were acquired from Potomac Electric Power Company (“PEPCO”) in December 2000. These facilities consist of coal and oil fired baseload units as well as coal, gas and oil fired intermediate and peaking units in Maryland and Virginia. Our largest facility in the region, the Chalk Point facility, has two coal fired baseload units, two oil and gas fired intermediate units and seven either oil fired or oil and gas fired peaking units, totaling 2,429 MW of capacity. The next largest facility, the Morgantown facility, consists of two coal and oil fired baseload units and six oil fired peaking units, totaling 1,492 MW of capacity. The Dickerson facility has three coal fired baseload units and three peaking units, totaling 853 MW of capacity, and the Potomac River Station, a coal fired facility, has three baseload and two intermediate units, totaling 482 MW of capacity.

Power generated by our Mid-Atlantic facilities is sold into the PJM market. For a discussion of the PJM market, see “Regulatory Environment—U.S. Public Utility Regulation” below. In connection with the acquisition of the Mid-Atlantic facilities from PEPCO in 2000, we, through Mirant Americas Energy Marketing, agreed to supply PEPCO its full load requirement in the District of Columbia under a transition power agreement (“TPA”), which expired in January 2005 (the “DC TPA”). There was also a similar TPA in place to supply PEPCO’s load in Maryland, which expired in June 2004 (the “Maryland TPA”).

Also, in connection with our acquisition of the Mid-Atlantic facilities from PEPCO in 2000, we agreed to purchase from PEPCO all power it received under long-term power purchase agreements with Ohio Edison Company (“Ohio Edison”) and Panda-Brandywine L.P. (“Panda”) that expire in 2005 and 2021, respectively. We and PEPCO entered into a contractual arrangement (the “PEPCO Back-to-Back Agreement”) with respect to PEPCO’s agreements with Panda and Ohio Edison under which (1) PEPCO agreed to resell to us all “capacity, energy, ancillary services and other benefits” to which it is entitled under those agreements; and (2) we agreed to pay PEPCO each month all amounts due from PEPCO to Panda or Ohio Edison for the immediately preceding month associated with such capacity, energy, ancillary services and other benefits. Under the PEPCO Back-to-Back Agreement, we are obligated to purchase power from PEPCO at prices that are significantly higher than existing market prices for power in the PJM market. On August 28, 2003, we filed a motion with the Bankruptcy Court to reject the PEPCO Back-to-Back Agreement. On December 9, 2004, we notified PEPCO and the Bankruptcy Court that we were suspending all future payments to PEPCO under the PEPCO Back-to-Back Agreement. For further information, see “Item 3. Legal Proceedings.”

Since the expiration of the Maryland TPA in June 2004 and the expiration of the DC TPA in January 2005, Mirant Americas Energy Marketing has been hedging the output of the Mid-Atlantic portfolio in the bilateral market as described previously. The terms for these transactions extend into 2006. In addition, Mirant Americas Energy Marketing enters into structured transactions with entities serving load in the greater Washington, D.C. area. Structured transactions are inherently more complicated than bilateral transactions, and we look to extract value over the mid-point of the market for such transactions. The terms for these transactions extend into 2006 as well.

Mirant Americas Energy Marketing also has participated in standard offer service auctions in Maryland and Washington, D.C. Power sales, made either directly through these functions or indirectly through subsequent market transactions that are a result of the auction process, serve as economic hedges for the Mid-Atlantic assets.

Northeast Region

We directly own or operate generating facilities in the Northeast region consisting of approximately 3,063 MW of capacity. The Northeast region is comprised of the New York and New England sub-regions.

The Mirant New York facilities were acquired from Orange and Rockland Utilities, Inc. and Consolidated Edison Company of New York, Inc. in June 1999. The New York generating facilities consist of the Bowline and Lovett facilities and various smaller generating facilities comprising a total of approximately 1,675 MW of capacity. The Bowline facility is a 1,133 MW dual fueled (natural gas and oil) facility comprised of two intermediate units. The Lovett facility consists of two baseload units capable of burning coal and gas comprising a total of 348 MW and a peaking unit capable of burning gas or oil comprising 63 MW. The smaller New York plant operations include two peaking units (the Hillburn gas turbine station and the Shoemaker gas turbine station), three hydroelectric stations (Mongaup 1-4, Swinging Bridge 1-2 and Rio 1-2) and an operational interest in the Grahamsville Hydroelectric Station comprising a total of 132 MW. An expansion at the Bowline facility, a 750 MW natural gas and distillate oil fired combined cycle unit, is currently suspended.

The Mirant New England facilities, with a total capacity of 1,388 MW, were acquired from subsidiaries of Commonwealth Energy System and Eastern Utilities in December 1998. The New England generating facilities consist of the Canal station, the Kendall station, the Martha’s Vineyard diesels and the Wyman Unit 4 interest. The Canal and Kendall facilities, consisting of approximately 1,109 MW and 256 MW of generating capacity, respectively, are designed to operate during periods of intermediate and peak demand, and are located in close proximity to Boston. The Kendall facility has been repowered since its acquisition and is now a natural gas combined cycle facility capable of producing both steam and electricity for sale. Both the Canal and Kendall facilities possess the ability to burn both natural gas and fuel oil. The Martha’s Vineyard diesels, with 14 MW of capacity, supply electricity on the island of Martha’s Vineyard during periods of high demand or in the event of a transmission interruption. The Wyman Unit 4 interest is an approximate 1.4% ownership interest (equivalent to 8.8 MW) in the 614 MW Wyman Unit 4 located on Cousin’s Island, Yarmouth, Maine. It is primarily owned and operated by the Florida Power and Light Group.

Generation is sold from our Northeast assets through a combination of bilateral contracts and spot market transactions, as well as structured transactions. The Mirant New York plants participate in a market operated by the Independent System Operator of New York (“NYISO”). The capacity, energy and ancillary services from the Mirant New England generating units are sold into the New England Power Pool (“NEPOOL”) through our commercial operations. NEPOOL is administered by the ISO of New England (“ISO-NE”). For a discussion of the NYISO, NEPOOL and the ISO-NE, see “Regulatory Environment—U.S. Public Utility Regulation” below.

Market fundamentals in the NYISO do not permit us to operate the Lovett facility on an economic basis as a merchant generation facility because of upcoming required environmental capital expenditures and property taxes associated with the facility. Our current plan is to retire the Lovett facility, starting with Unit 5 in 2007 and Units 3 and 4 in 2008. Market fundamentals in NEPOOL do not permit us to operate the Kendall facility on an economic basis as a merchant facility. Our plan has been to shutdown, at least temporarily, the Kendall facility from January 2006 through December 2007, with the possibility of restarting operations as early as January 2008. However, the ISO-NE has determined that a small part of the capacity of the Kendall facility is needed for reliability and has negotiated a Reliability-Must-Run (“RMR”) contract with respect to the Kendall facility with a term of approximately one year. We filed this contract with the Federal Energy Regulatory Commission (“FERC”) for RMR status under the existing tariff on October 7, 2004 and are currently waiting for FERC approval or acceptance of the agreement and the revenue requirements contained within it. We and the other parties in this proceeding are currently in settlement negotiations. We and NStar Electric & Gas Corp., the local contracting utility, have reached a preliminary agreement that, once finalized and accepted or approved by the FERC, will resolve virtually all of the issues raised in this proceeding.

Mid-Continent Region

The Mirant Mid-Continent facilities, consisting of an equity interest in roughly 2,668 MW, are located in the Midwest and Southeast markets. The Midwest facilities, which include our Sugar Creek and Mirant Zeeland facilities, consist of over 1,372 MW of generating capacity and are all natural gas fired peaking and/or intermediate units. The Southeast facilities include three facilities, Wrightsville, West Georgia and Shady Hills, with a net equity interest of 1,296 MW.

The Sugar Creek facility is a combined cycle facility with the capability to produce 535 MW. Located in West Terre Haute, Indiana, the Sugar Creek facility has the physical capability to be interconnected with either the Cinergy or American Electric Power, Inc. (“AEP”) systems. Cinergy is a member of the MISO, and AEP is a member of the PJM market. The facility is eligible to deliver energy and participate in the energy, capacity and ancillary markets of the PJM market.

The Mirant Zeeland facility, a combined cycle facility in Zeeland, Michigan, has generating capacity of 837 MW and is interconnected with the International Transmission Company, which is a member of the MISO. Both the Zeeland and Sugar Creek facilities operate under the East Central Area Reliability Coordination Agreement (“ECAR”).

The West Georgia facility in Thomaston, Georgia and the Shady Hills facility in Pasco County, Florida consist of gas and oil fired combustion turbines serving peak loads of approximately 605 MW and 468 MW, respectively.

The Wrightsville facility consists of gas fired intermediate/peaking units with generating capacity of 438 MW. In 2004, we mothballed this facility, pending regional recovery of power prices. In February 2005, we entered into an agreement to sell the Wrightsville facility to Arkansas Electric Cooperative Corporation (“AECC”), subject to Bankruptcy Court approval and certain other regulatory and third-party consents and approvals. We expect the sale of the Wrightsville facility to close in 2005.

For a discussion of MISO and ECAR, see “Regulatory Environment—U.S. Public Utility Regulation” below.

West Region

Our West region facilities consist of a net equity interest in 3,602 MW of gas fired generating capacity in California, Oregon, Nevada and Texas.

The generating assets in California provide a total capacity of 2,347 MW and consist of the Pittsburg, Contra Costa and Potrero plants, which include facilities operating at both intermediate and peak demand levels located in, or in close proximity to, San Francisco. The Pittsburg and Contra Costa plants consist of five intermediate natural gas fired steam generating units with approximately 1,985 MW of generating capacity located approximately ten miles apart along the Sacramento/San Joaquin River Delta. The Potrero plant has one baseload natural gas fired conventional steam generating unit and three peaking distillate fueled combustion turbines with a combined capacity of 362 MW.

The majority of our California assets are subject to RMR agreements with the California Independent System Operator (“CAISO”). These agreements are described further under “Regulatory Environment—U.S. Public Utility Regulation” below. The Mirant California subsidiaries currently have the largest portfolio of units which operate under RMR contracts, reflecting the fact that the location of these units is key to the electric system reliability. Contra Costa Unit 6 is not a party to an RMR agreement, and thus functions solely as a merchant facility in the CAISO. Mirant Americas Energy Marketing sells the output of Contra Costa Unit 6 into the market through bilateral transactions with utilities and other merchant players.

In October 2004, the CAISO notified us that the RMR contract for Pittsburg Unit 7 would not be renewed for 2005. On January 3, 2005, Mirant Americas Energy Marketing announced that it was seeking proposals for a one-, two- or three-year tolling arrangement for Pittsburg Unit 7 and Contra Costa Unit 6. We received bids on January 28, 2005, and we are in the process of evaluating these bids at this time. If this request for proposal does not result in an acceptable contract for Pittsburg Unit 7, we intend to retire Pittsburg Unit 7, consisting of 682 MW, by the middle of 2005, due to new nitrogen oxide (“NOx”) emissions standards that would require significant capital and operating and maintenance expenditures.

Coyote Springs is a 280 MW intermediate combined-cycle gas fired plant, located in Boardman, Oregon, that began commercial operations in July 2003. In October 2004, we entered into an agreement to sell our 50% interest in Coyote Springs to Avista Utilities, subject to Bankruptcy Court and the FERC approval. The Bankruptcy Court and the FERC approved the sale in December 2004 and the sale was completed for $63 million in January 2005.

The Apex generating facility, a 500 MW intermediate gas combined-cycle facility located near Las Vegas, Nevada, was developed by us and began commercial operations in May 2003.

We operate two facilities in Texas: the Bosque facility and the Wichita Falls facility. The Bosque facility consists of a gas fired combustion turbine with a corresponding steam turbine (combined cycle unit) with a capacity of 230 MW that is available to serve baseload and intermediate demand. Additionally, Bosque Units 1 and 2 are gas fired peakers with a capacity of 154 MW each. The Wichita Falls facility is a combined cycle facility and consists of three gas turbines and a steam turbine with a total capacity of 77 MW. The Wichita Falls facility primarily sells its electrical output to the merchant market.

Both the Bosque and Wichita Falls facilities operate in the Electric Reliability Council of Texas (“ERCOT”) market. For a discussion of ERCOT, see “Regulatory Environment—U.S. Public Utility Regulation” below.

International

Through various subsidiaries, we own or control under operating agreements various generation, transmission and distribution operations in the Philippines and the Caribbean. A complete list of our international properties is contained in “Item 2. Properties.”

Philippines

We, indirectly through our Philippine subsidiaries, have ownership, leasehold or similar interests in nine generating facilities in the Philippines. As of December 31, 2004, our net ownership interest in the generating capacity of these facilities was approximately 2,300 MW. Over 80% of the generation capacity in the Philippines facilities is sold under long-term energy conversion agreements with the Philippine government-owned National Power Corporation (“NPC”). NPC acts as both the fuel supplier and the energy purchaser under the energy conversion agreements for our Pagbilao, Sual, Navotas II and Ilijan facilities. NPC procures all of the fuel necessary for generation under an energy conversion agreement, at no cost to the respective subsidiary or associate, and has substantially all fuel risks and fuel related obligations under the agreement other than those relating to the fuel burning efficiency of the facility. In addition to the energy conversion agreements with NPC, our Sual and Pagbilao subsidiaries have joint marketing agreements with NPC for excess capacity of 218 MW and 35 MW, respectively. Currently, electricity from the excess capacity of our Sual facility is provided to select markets such as economic zones, industries and private electric distribution companies and cooperatives.

Under the energy conversion agreements, our respective subsidiaries and associates receive both fixed capacity fees and variable energy fees. Currently, approximately 90% of our revenues with respect to our Philippine operations come from fixed capacity charges under long-term contracts that are paid without regard to the dispatch level of the facility. Nearly all of our capacity fees are denominated in U.S. dollars. Energy fees have both U.S. dollar and Philippine peso components that are indexed to inflation. The majority of the obligations of NPC under the energy conversion agreements are guaranteed by the full faith and credit of the Philippine government. The energy conversion agreements are executed under the Philippine government’s build-operate-transfer program. At the end of the term of each energy conversion agreement, the facility is to be transferred to NPC, free from any lien or payment of compensation. The energy conversion agreements for our Navotas II, Sual, Pagbilao and Ilijan facilities expire in July 2005, October 2024, August 2025 and January 2022, respectively.

Our larger Philippine projects have been granted preferred or pioneer status that, among other things, has qualified them for income tax holiday incentives of three to six years. The income tax holiday incentive expired in June 2002 for our Pagbilao facility and will expire in October 2005 and January 2008 for our Sual and Ilijan facilities, respectively. The amount of benefit from these holiday incentives is $54 million, $50 million, and $69 million for 2004, 2003, and 2002, respectively.

Deregulation and Privatization

In June 2001, the Philippine Congress approved and passed into law the Electric Power Industry Reform Act (“EPIRA”), providing the mandate and the framework to introduce competition in the Philippine electricity market. EPIRA also provides for the privatization of the assets of NPC, including its generation and transmission assets, as well as its contracts with independent power producers (“IPPs”). The deregulation of the Philippine electricity industry and the privatization of NPC have been long anticipated, and EPIRA is not expected to have a material impact on our existing Philippine assets or our operations.

EPIRA provides that competition in the retail supply of electricity and open access to the transmission and distribution systems would occur within three years from its effective date. Prior to June 2002, concerned government agencies were to establish a wholesale electricity spot market, ensure the unbundling of transmission and distribution wheeling rates and remove existing cross-subsidies provided by industrial and commercial users to residential customers. As of December 2004, most of these changes have started to occur but are considerably behind the schedule set by the Philippine Department of Energy.

Under EPIRA, NPC’s generation assets are to be sold through transparent, competitive public bidding, while all transmission assets are to be transferred to the Transmission Company, initially a government-owned entity that is to eventually be privatized. The privatization of these NPC assets has been delayed and is considerably behind the schedule set by the Philippine Department of Energy.

EPIRA also created the Power Sector Assets and Liabilities Management Corporation (“PSALM”), which is to accept transfers of all assets and assume all outstanding obligations of NPC, including its obligations to IPPs. One of PSALM’s responsibilities is to manage these contracts with IPPs after NPC’s privatization. PSALM also is responsible for privatizing at least 70% of the transferred generating assets and IPP contracts no later than three years from the effective date of the law. As of December 2004, the work related to the planned privatization has commenced, but is considerably behind schedule.

Consistent with the announced policy of the Philippine government, EPIRA contemplates continued payment of NPC’s obligations under its energy conversion agreements. The energy conversion agreements of our Philippine subsidiaries are not assignable without consent. We are in continuing discussions with NPC and PSALM on a proposal to add PSALM as an additional obligor under its existing IPP contracts. Additionally, the Philippine government issued performance undertakings to guarantee the performance of NPC’s obligations under certain energy conversion agreements.

Philippine IPP Review

Pursuant to EPIRA, a governmental inter-agency committee reviewed all IPP contracts and reported that some contracts had legal or financial issues requiring further review or action, including contracts with our subsidiaries. Subsequently, we, along with PSALM, the Philippine Department of Energy and the Philippine Department of Justice entered into a letter of agreement establishing a general framework (the “General Framework Agreement”) for resolving all outstanding issues raised by the committee about IPP contracts with our subsidiaries.

In March 2003, the conditions precedent for our Sual and Pagbilao components of the General Framework Agreement were satisfied and the implementation agreements relating to both became effective. As a result of the General Framework Agreement, the original energy conversion agreements for our Sual and Pagbilao facilities remain intact and are reaffirmed with no resultant material financial impact.

Caribbean

Our net ownership interest in the generating capacity of our Caribbean plants is approximately 1,000 MW.

Grand Bahama Power Company (“Grand Bahama Power”)

We own a 55.4% interest in Grand Bahama Power, an integrated electric utility company that generates, transmits, distributes and sells electricity on Grand Bahama Island. Grand Bahama Power has the exclusive right and obligation to supply electric power to the residential, commercial and industrial customers on Grand Bahama Island. Grand Bahama Power’s rates are approved by the Grand Bahama Port Authority.

The Power Generation Company of Trinidad and Tobago (“PowerGen”)

We own a 39% interest in PowerGen, a power generation company that owns and operates three plants located on the island of Trinidad. The electricity produced by PowerGen is provided to the Trinidad and Tobago Electricity Commission (“T&T EC”), the state-owned transmission and distribution monopoly, which serves approximately 347,000 customers on the islands of Trinidad and Tobago and

which holds a 51% interest in PowerGen. PowerGen has a power purchase agreement for approximately 820 MW of capacity and spinning reserve with the T&T EC, which expires in 2009 and is unconditionally guaranteed by the government of Trinidad and Tobago. Under this contract, the fuel is provided by the T&T EC.

In response to a September 3, 2004 request for proposals issued by National Gas Company of Trinidad and Tobago Limited (“NGC”), on November 30, 2004, PowerGen submitted a bid to build new generation and provide electric generation capacity under long term power purchase agreements to National Energy Corporation (“NEC”) and T&T EC. The request for proposals contemplates a need of between 200 MW and 250 MW for T&T EC and possibly a further need of between 400 MW and 540 MW for NEC with commercial operations dates between the third quarter of 2006 and March 2008. PowerGen will likely have definite resolution related to this bid by mid-2005.

Jamaica Public Service Company Limited (“JPS”)

We own an 80% interest in JPS, a fully integrated electric utility company that generates, transmits, distributes and sells electricity on the island of Jamaica. JPS operates under a 20-year All-Island Electric License that expires in 2021 and that provides JPS with the exclusive right to sell power in Jamaica. JPS has installed generation capacity of 600 MW, and it purchases an additional 146 MW of firm capacity from three IPPs under long-term purchase agreements and an additional 20 MW of energy from a wind farm on an as-available basis. JPS supplies electric power to approximately 540,000 residential, commercial and industrial customers in Jamaica. At present, JPS is regulated by the Office of Utilities and Regulation under a price cap model with rate cases held every five years and with interim adjustments indexed to inflation and foreign exchange movements.

Curacao Utilities Company (“CUC”)

We own a 25.5% interest in CUC at the Isla Refinery in Curacao, Netherlands Antilles. The 133 MW facility provides electricity, steam, desalinated water and compressed air to the refinery and up to 45 MW of electricity to the Curacao national grid.

Aqualectra

We own a $40 million convertible preferred equity interest in Aqualectra, an integrated water and electric company in Curacao, Netherlands Antilles, owned and operated by the government. Aqualectra has electric generating capacity of 235 MW and drinking water production capability of 69,000 cubic meters per day. Aqualectra serves approximately 65,000 electricity and water customers. We receive 16.75% preferred dividends on our $40 million investment on a quarterly basis. Aqualectra has a call option and we have a put option, both of which became exercisable for the three-year period beginning on December 19, 2004. We also have an option to convert our convertible preferred equity interest in Aqualectra to common shares during the same three-year period beginning December 19, 2004.

Regulatory Environment

U.S. Public Utility Regulation

The U.S. electricity industry is subject to comprehensive regulation at the federal, state and local levels. At the federal level, the FERC has exclusive jurisdiction under the Federal Power Act (the “Federal Power Act”), over sales of electricity at wholesale and the transmission of electricity in interstate commerce. A Mirant subsidiary that owns generating facilities selling at wholesale or that markets electricity at wholesale outside of ERCOT is a “public utility” subject to the FERC’s jurisdiction under the Federal Power Act. These Mirant subsidiaries must comply with certain FERC reporting requirements and FERC-approved market rules and are subject to FERC oversight of mergers and acquisitions, the

disposition of FERC-jurisdictional facilities, and the issuance of securities, for which blanket authority has been granted. In addition, under the Natural Gas Act (“NGA”), the FERC has limited jurisdiction over certain sales for resale of natural gas, but does not regulate the prices received by the Mirant subsidiary that markets natural gas.

The FERC has authorized the public utility Mirant subsidiaries to sell energy and capacity at wholesale market-based rates and has authorized some of the public utility Mirant subsidiaries to sell certain ancillary services at wholesale market-based rates. The majority of the output of the generation facilities owned by Mirant’s public utility subsidiaries in the United States is sold pursuant to this authorization, although certain of our facilities sell their output under cost-based RMR agreements, as explained below. The FERC may revoke or limit our market-based rate authority if it determines that we possess market power. The FERC requires that our subsidiaries with market-based rate authority, as well as those with blanket certificate authorization permitting market-based sales of natural gas, adhere to certain market behavior rules and codes of conduct, respectively. If our subsidiary violates the market behavior rules or codes of conduct, the FERC may require a disgorgement of profits or revoke its market-based rate authority or blanket certificate authority. If the FERC were to revoke market-based rate authority, the Mirant subsidiary would have to file a cost-based rate schedule for all or some of its sales of electricity at wholesale. If the FERC revoked the blanket certificate authority of a Mirant subsidiary, it would no longer be able to make certain sales of natural gas.

In an effort to promote greater competition in wholesale electricity markets, the FERC has encouraged the formation of ISOs and RTOs. In those areas where ISOs or RTOs control the regional transmission systems, market participants have expanded access to transmission service. ISOs and RTOs also may operate real-time and day-ahead energy and ancillary services markets, which are governed by FERC-approved tariffs and market rules. Some RTOs and ISOs also operate capacity markets. Changes to the applicable tariffs and market rules may be requested by market participants, state regulatory agencies and the system operator, and such proposed changes, if approved by the FERC, could have an impact on our operations and business plan. While participation by transmission-owning public utilities in ISOs and RTOs has been and is expected to continue to be voluntary, the majority of such public utilities in New England, New York, the Mid-Atlantic, the Midwest and California have joined the existing ISO/RTO for their respective region. The majority of our facilities operate in these ISO/RTO regions.

We are not currently subject to the Public Utility Holding Company Act of 1935, as amended (“PUHCA”), and do not anticipate becoming so unless we acquire the securities of a public utility company or public utility facility that does not qualify as an exempt wholesale generator, a foreign utility company, or a qualifying small power production or cogeneration facility. Currently, our subsidiaries owning generation in the United States are exempt wholesale generators under PUHCA, and all of our subsidiaries owning generation outside the United States are either foreign utility companies or exempt wholesale generators.

At the state and local levels, regulatory authorities have historically overseen the distribution and sale of retail electricity to the ultimate end user, as well as the siting, permitting and construction of generating and transmission facilities. Our existing generation may be subject to a variety of state and local regulations, including regulations regarding the environment, health and safety, maintenance, and expansion of generation facilities. Our subsidiaries that sell at the retail level in states that have a retail access program may be subject to state certification requirements and to bidding rules to provide default service to customers who choose to remain with their regulated utility distribution companies.

Mid-Atlantic Region—Our Mid-Atlantic assets sell power into the markets operated by PJM, which the FERC approved to operate as an ISO in 1997 and as an RTO in 2002. We have access to the PJM transmission system pursuant to PJM’s Open Access Transmission Tariff. PJM operates the PJM Interchange Energy Market, which is the region’s spot market for wholesale electricity, provides ancillary

services for its transmission customers and performs transmission planning for the region. To account for transmission congestion and losses, PJM calculates electricity prices using a locational-based marginal pricing model and dispatches electricity on a security constrained least cost basis. On January 24, 2005, the FERC issued an order changing PJM’s mitigation rules for frequently mitigated units (those mitigated in excess of 80% of annual running hours), as well as the retirement policy rules. The revised policy provides some opportunity for increased compensation for frequently mitigated units. Under the old rules, such units were restricted to bidding variable costs plus 10% when a transmission constraint caused the unit to be selected out of economic merit order. Under the new rules, the restriction is variable costs plus $40/megawatt hour (“MWh”). Units mitigated less than 80% of the time remain under the old “cost plus 10%” policy. PJM also proposed a revised generation retirement policy that sets forth a process by which PJM will address a request by a generation owner to deactivate a unit, determine whether established reliability criteria would be violated if the unit were deactivated, and provide compensation to the generation owner when a unit proposed for deactivation is required to continue operating for reliability. This proposal was also approved. Both changes are currently effective, although possibly subject to revision via requests for rehearing. PJM is also developing a redesign of its capacity obligations, referred to as a Reliability Pricing Model (“RPM”), and the RPM is anticipated to be filed at the FERC in late March 2005. If filed in a form resembling stakeholder discussions to date, and ultimately approved by the FERC, this proposal would also provide some opportunity for an improved revenue stream for Mirant-owned capacity. However, the FERC’s response to these issues and the final impact, if any, on our facilities cannot be determined at this time.

PJM has greatly expanded its system over the last two years with the addition of the service areas of Allegheny Power, Commonwealth Edison, AEP, Duquesne Light and Dayton Power & Light (“DP&L”) and the anticipated addition of Dominion-Virginia Power in 2005. In the fall of 2004, PJM completed its integration of AEP and DP&L into the PJM RTO. For purposes of determining deliverability to the unforced capacity market (“UCAP market”), AEP and DP&L were deemed to be capable of providing capacity to all areas of PJM. This effectively provided the same comparability of delivery for a generator in western Ohio to deliver capacity to the PEPCO zone where our assets are located. The deliverability standard and the additional capacity that the new entrants are now capable of providing to the UCAP market in PJM has severely depressed forward pricing for capacity. PJM has proposed a new RPM that will provide for recognition of locational deliverability zones. The model proposes a phase in to locational zones over a four-year period. In addition, PJM and MISO have been directed by the FERC to establish a common and seamless market, an effort that is largely dependent upon MISO’s ability to first establish and operate its markets.

Northeast Region—Our New York plants participate in a market controlled by NYISO, which replaced the New York Power Pool (“NYPP”). NYISO provides statewide transmission service under a single tariff and interfaces with neighboring market control areas. To account for transmission congestion and losses, NYISO calculates energy prices using a locational-based marginal pricing model that is similar to that used in the PJM and ISO-NE. NYISO also administers a spot market for energy, as well as markets for installed capacity, operating reserves and regulation service. NYISO employs an Automated Mitigation Procedure (“AMP”) in its day-ahead market that automatically caps energy bids when certain established bid screens indicate a bidder may have market power. On January 14, 2005, the U.S. Court of Appeals for the D.C. Circuit vacated and remanded the FERC’s orders approving the AMP. The AMP provisions of the NYISO’s tariff remain in effect pending further proceedings. In addition, the NYISO’s locational capacity market rules use a “demand curve” mechanism to determine for every month the required amount of installed capacity as well as installed capacity prices for three locational zones: New York City, Long Island and the rest of New York. Our facilities operate outside of New York City and Long Island. The demand curve is derived for each of the three zones by setting the price of installed capacity for 118% of peak load (peak load plus an 18% reserve margin) at the assumed price for a new generating plant to serve peak demand (“new entrant”) and then sloping the “demand curve” for installed capacity downward to reflect

additional amounts of capacity beyond the 118%. The FERC approved the new entrant price for use from the summer of 2003 to the spring of 2005, and required NYISO to file three proposed new entrant prices that would be applicable from the summer of 2005 through the spring of 2008. On January 7, 2005, NYISO filed revisions to its services tariff to define the demand curves for capability years 2005/2006, 2006/2007 and 2007/2008. A FERC order is expected on the 2005 through 2008 demand curves in March 2005. The FERC’s 2003 order approving the existing demand curves has been appealed by a trade association to the U.S. Court of Appeals for the D.C. Circuit.

Our New England plants also participate in a market administered by ISO-NE, under contract to NEPOOL, which is a voluntary association of electric utilities and other market participants in Connecticut, Maine, Massachusetts, New Hampshire, Rhode Island and Vermont. The FERC has approved a RTO for the New England region (“RTO-NE”), which assumed responsibility for the operation of transmission systems and administration and settlement of the wholesale electric energy, capacity and ancillary services markets on February 1, 2005. ISO-NE utilizes a locational marginal pricing model, with a price mitigation method similar to NYISO’s AMP. In 2004, the FERC approved a locational installed capacity market for ISO-NE based on the “demand curve” concept also used by NYISO, to be implemented in January 2006. A hearing on the demand curve parameters was held in late February and early March and a FERC order on these proposals is expected in mid to late-2005.

Mid-Continent Region—Our Mid-Continent plants are located in the Midwest and Southeast markets. In the Midwest markets, our plants participate in a market to be administered by MISO. The FERC approved the formation of MISO in 2001, and it currently administers transmission operations. MISO intends to operate energy markets similar to those operated by PJM and has received FERC approval to commence operating energy markets on March 1, 2005. However, due to a desire to test thoroughly before implementation, MISO has voluntarily elected to delay actual implementation until April 1, 2005. MISO plans to use locational marginal pricing for energy and associated financial transmission rights so that market participants may manage the risks associated with moving energy from generation sources to load. The market plan also includes both a day-ahead energy market based on firm financial commitments to provide energy and a real-time market for physical supply and demand. MISO proposes to implement a capacity market by June 1, 2006, but has not yet identified a specific capacity market design. MISO also proposes to implement mitigation rules similar to those of NYISO, but will likely not implement an automatic price cap. While tangible progress continues to be made toward actual implementation, we still cannot provide assurance regarding whether or when MISO will commence operation of its new market or what the impact on our earnings could be. The Sugar Creek facility is interconnected to both MISO and PJM, through Cinergy and AEP’s transmission system, and can sell into either market (though not into both simultaneously). Sugar Creek is eligible to participate in the PJM capacity and energy markets.

In the Southeast, we currently sell electric energy and capacity from our facilities under bilateral contracts that contain terms and conditions that are not standardized and that have been negotiated on an individual basis. Customers in this region include investor-owned, vertically integrated utilities, municipalities and electric cooperatives.

West Region—Our West plants are located in the Western Interconnection and the ERCOT market in Texas. California accounts for roughly 40% of the energy consumption in the Western Interconnection. Approximately 75% of California’s demand is served from facilities in the CAISO control area, which includes our California facilities. The CAISO schedules transmission transactions, arranges for necessary ancillary services and administers a real-time balancing energy market. The CAISO has proposed changes to its market design to more closely mirror the eastern RTO markets. The market redesign has been delayed several times, with full implementation now expected in 2007 or 2008. The California Public Utility Commission (“CPUC”) has taken the lead role for establishing capacity requirements in California and has ordered California’s load-serving entities to meet specific load and reserve requirements beginning in the summer of 2006. The CAISO has not proposed a capacity market mechanism in its market redesign.

The majority of our assets in California are subject to RMR agreements with the CAISO. These agreements require certain of our facilities, under certain conditions and at the CAISO’s request, to operate at specified levels in order to support grid reliability. Under the RMR agreements, we recover through fixed charges either a portion (RMR Contract Condition 1) or all (RMR Contract Condition 2) of the annual fixed revenue requirement of the generation assets as approved by the FERC (the “Annual Requirement”). Our California generation assets operating under RMR Contract Condition 1 depend on revenue from sales of the output of the plants at market prices to recover the portion of the plant’s fixed costs not recovered in RMR payments. For these generation assets, only a percentage of the Annual Requirement, as approved by the FERC, can be recovered through RMR payments, whereas RMR Contract Condition 2 Units recover 100%. The contracts require yearly filings for FERC approval of the Annual Requirement for the following calendar year.

The CAISO imposes a $250/MWh cap on prices for energy and capacity and has implemented an AMP similar to that used by NYISO. Owners of non-hydroelectric generation in California, including certain of our facilities, must offer power in the CAISO’s spot markets if the output is not scheduled for delivery within the hour. For the remaining units located outside of California, but within the Western Interconnection, there is no single entity responsible for a centralized bid-based market. Outside of California, the primary markets in the West today are bilateral and adhere to the reliability standards of the Western Electricity Coordinating Council (“WECC”). Although we are active participants in initiatives to establish new ISOs or RTOs in the West, we can neither predict when, nor if, such entities will emerge nor if market developments will have a positive or negative impact on future earnings from our Western assets.

Our Texas plants participate in a market administered by the ERCOT ISO, which manages a major portion of the state’s electric power grid. ERCOT ISO oversees competitive wholesale and retail markets resulting from electricity restructuring in Texas and protects the overall reliability of the ERCOT grid. ERCOT ISO, the only ISO that manages both wholesale and retail market operations, is regulated by the Public Utility Commission of Texas (“PUCT”). The PUCT conducts market monitoring within ERCOT. Price mitigation measures in ERCOT include a $1,000 per MWh price cap and RMR-type contracts for congested areas. To improve congestion management, the PUCT recently established a rulemaking proceeding on wholesale market design issues that will focus on adding a congestion management mechanism based on locational pricing, similar to that used in PJM, and a day-ahead market. A revised market design is expected to be in place by 2005 but, as with other evolving market structures, we cannot provide assurance as to when the enhancements will be completed and implemented, or what the impact on earnings in the ERCOT market will be.

Environmental Regulation

United States

Air Emissions Regulations: Our business is subject to extensive environmental regulation by federal, state and local authorities, which requires continuous compliance with regulations and conditions established by their operating permits. Our most significant environmental requirements in the United States arise under the federal Clean Air Act of 1990, as amended (the “Clean Air Act”), and similar state laws. Under the Clean Air Act, we are required to comply with a broad range of requirements and restrictions concerning air emissions, operating practices and pollution control equipment. Several of our facilities are located in or near metropolitan areas, such as New York City, Boston, San Francisco and Washington D.C., which are classified by the U.S. Environmental Protection Agency (“EPA”) as not achieving certain federal ambient air quality standards. The regulatory classification of these areas subjects our operations in these areas to more stringent air regulation requirements, potentially including, in some cases, required emission reductions. Also, states are required by Section 185 of the Clean Air Act to impose additional fees for air emissions from major sources in areas that are classified as severe non-attainment for ozone and that fail to meet the attainment deadline. For example, the Virginia and

Maryland suburbs of Washington D.C. are part of the Washington, D.C. non-attainment area and currently are classified as severe non-attainment for ozone, applying a one-hour ozone standard. The EPA has designated this area as moderate non-attainment applying a new eight-hour standard and has indicated that it will rescind the one-hour ozone standard in June 2005. If it does not rescind the one-hour standard and the November 2005 attainment deadline under the one hour standard is not met, Section 185 of the Clean Air Act would require Virginia and Maryland to begin imposing additional fees on major sources of ozone beginning in 2006. The formula for determining this fee has not been finally established, but is likely to be a significant cost for our Mid-Atlantic plants. On September 27, 2004, we entered into a conditional consent decree resolving an enforcement proceeding with the state of Virginia and EPA. The consent decree was also entered into by the state of Maryland and the Department of Justice (the “DOJ”) on behalf of the EPA. The consent decree creates annual and ozone season caps on NOx emissions, provides for certain additional pollution controls, supplemental environmental projects to be done at the Potomac River plant and a $500,000 fine. Approvals by the Federal District Court in Alexandria and the Bankruptcy Court are being sought.

In the future, we anticipate increased regulation of generation facilities under the Clean Air Act and applicable state laws and regulations concerning air quality. The EPA and several states in which we operate are in the process of enacting more stringent air quality regulatory requirements.

For example, the EPA promulgated regulations (referred to as the “NOx SIP Call”), which establish emission cap and trade programs for NOx emissions from electric generating units in most of the Eastern states. These programs were implemented beginning May 2003 in the Northeast and May 2004 in the rest of the region. Under these regulations, a plant receives an allocation of NOx emission allowances, and if a plant exceeds its allocated allowances, the plant must purchase additional, unused allowances from other regulated plants or reduce emissions, which could require the installation of emission controls. Our plants in Maryland, New York and Massachusetts complied with similar state and regional NOx emission cap and trade programs from 1999 to 2002, which has been superseded by the EPA NOx cap and trade program. Some of our plants in these states are required to purchase additional NOx allowances to cover their emissions and maintain compliance. The cost of these allowances may increase in future years and may result in some of our plants reducing NOx emissions through additional controls, the cost of which could be significant but would be offset in part by the avoided cost of purchasing NOx allowances to operate the plant.

The EPA also has promulgated regulations that establish emission cap and trade programs for sulfur dioxide (“SO2”) emissions (the “Acid Rain Program”) from electric generating units in the United States. This Acid Rain Program was implemented in two phases. Phase I began in 1995 and affected 263 units at 110 mostly coal-burning electric utility plants located in 21 Eastern and Midwestern states. Phase II, which began in 2000, tightened the annual emissions limits imposed on Phase I plants and also set restrictions on smaller, cleaner plants fired by coal, oil and gas encompassing over 2,000 units in all. The Acid Rain Program affects existing utility units serving generators with an output capacity of greater than 25 MW and all new utility units. The Acid Rain Program represents a dramatic departure from traditional command and control regulatory methods, which establish specific, inflexible emissions limitations with which all affected sources must comply. Instead, the Acid Rain Program introduces an allowance trading system that harnesses the incentives of the free market to reduce pollution. Under this system, affected utility units were allocated allowances based on their historic fuel consumption and a specific emissions rate. Each allowance permits a unit to emit one ton of SO2 during or after a specified year. Allowances may be bought, sold or banked. Anyone may acquire allowances and participate in the trading system. The Acid Rain Program set a permanent ceiling (or cap) of 8.95 million allowances for total annual allowance allocations to utilities. All of our facilities are in compliance with the requirements of the Acid Rain Program. Some of our plants have surplus allowances and some are required to purchase additional SO2 allowances to cover their emissions and maintain compliance. The costs of these allowances may increase in future years and may result in some of our plants reducing SO2 emissions through additional controls,

the cost of which could be significant but would be offset in part by the avoided cost of purchasing SO2 allowances to operate the plant.

The Acid Rain Program also has a NOx emission reduction program. This program only affects coal fired units and also was implemented in a two-phase approach in 1995 and 2000. This program is not a cap and trade program but identifies specific emission rates and/or control technology requirements. We have installed the NOx control technology and/or are meeting applicable emission rates. All our coal units are in compliance with requirements of the Acid Rain Program’s NOx emission reduction program. We foresee no additional expense to comply with this program.

The EPA has proposed regulations to govern mercury air emissions from coal fired power plants. This proposal offers alternate regulatory approaches, which include a cap and trade program that would go into effect in January 2010 and a maximum achievable control technology standard (unit specific emission standard) that would go into effect in December 2007, which may be extended by the EPA to December 2008. The mercury regulations are likely to require significant emission reductions from coal fired power plants. This rulemaking also proposes new regulations governing nickel air emissions from oil fired power plants, which would either go into effect in December 2007, with a possible one-year extension by the EPA to December 2008, or go into effect January 2010. The cost to comply with such requirements could be significant.

During the course of this decade, the EPA will be implementing new, more stringent ozone and particulate matter ambient air quality standards. It will also address regional haze visibility issues, which will result in new regulations that will likely require further emission reductions from power plants, along with other emission sources such as vehicles. To implement these air quality standards, the EPA promulgated the Clean Air Interstate Rule (“CAIR”) on March 10, 2005. The CAIR establishes in the eastern United States a more stringent SO2 cap and allowance-trading program and a year round NOx cap and allowance-trading program applicable to power plants. These cap and trade programs will be implemented in two phases, with the first phase going into effect in 2009 and more stringent caps going into effect in 2015.

These future mercury and nickel regulations and the CAIR would increase compliance costs for our operations and would likely require emission reductions from some of our power plants, which would necessitate significant expenditures on emission controls or have other impacts on operations. These rulemakings are likely to be finalized in early 2005. Until the final regulations are promulgated, we cannot predict whether the regulations will have a material adverse effect on our financial condition, cash flows and results of operations.

In addition to implementation of statutes already in existence, there are additional environmental requirements under strong consideration by the federal and various state legislatures. The Bush Administration has submitted Clean Air Act multi-emission reform legislation to Congress, which would promulgate a new emissions cap and trade program for NOx, SO2 and mercury emissions from power plants. This legislation would require overall reductions in these pollutants from national power plant emissions of approximately 50-75% phased in during the 2008 - 2016 timeframe, which is similar to the types of overall reductions likely to be required under the future EPA regulations discussed above. Other more stringent multi-emission reform legislation also has been proposed in Congress by some lawmakers. There are many political challenges to the passage of multi-emission reform legislation through Congress, and it is unclear whether any of this legislation ultimately will be enacted into law.

Various states where we do business also have other air quality laws and regulations with increasingly stringent limitations and requirements that will become applicable in future years to our plants and operations. We expect to incur additional compliance costs as a result of these additional state requirements, which could include significant expenditures on emission controls or have other impacts on our operations.

For example, the Commonwealth of Massachusetts has finalized regulations to further reduce NOx and SO2 emissions from certain power plants and to regulate carbon dioxide and mercury emissions for the first time. Mercury emission reductions will be required exclusively from coal fired facilities. These regulations, which become effective in the 2004-2008 timeframe, will apply to our oil fired Canal plant in the state, will increase our operating costs and will likely necessitate the installation of additional emission control technology.

Another example is in the San Francisco Bay Area, where we own power plants. NOx emission standards have become increasingly stringent on a specified schedule over a several year period, culminating in 2005. We will continue to apply our NOx implementation plan for these plants, which includes the installation of emission controls as well as the gradual curtailment and phasing out of one or more of our higher NOx emitting units.

Additionally, in 2003, the State of New York finalized air regulations that significantly reduced allowances for NOx and SO2 emissions from power plants through a state emissions cap and allowance-trading program, which will become effective during the 2004-2008 timeframe. This regulation will necessitate that we act on one, or a combination of the following options: install emission controls at some of our units to reduce emissions, purchase additional state NOx and SO2 allowances under the regulatory program or reduce the number of hours that units operate. We expect to incur additional compliance costs as a result of these additional state requirements, which could include significant expenditures on emission controls or have other impacts on operations.

These examples are illustrative but not a complete discussion of the additional federal and state air quality laws and regulations that we expect to become applicable to our plants and operations in the coming years. We will continue to evaluate these requirements and attempt to develop compliance plans that enable us to appropriately manage the costs and impacts.

Other Environmental Regulations: There are other environmental laws in the United States, in addition to air quality laws, that also affect our operations. We are required under the Clean Water Act to comply with effluent and intake requirements, technological controls and operating practices. Our wastewater discharges are permitted under the Clean Water Act, and our permits under the Clean Water Act are subject to review every five years. As with air quality regulations, federal and state water regulations are expected to increase and impose additional and more stringent requirements or limitations in the future. For example, in 2004, the EPA issued a new rule that imposes more stringent standards on the cooling water intakes for power plants. We expect to incur additional compliance costs to comply with this new rule.

Our facilities also are subject to several waste management laws and regulations in the United States. The Resource Conservation and Recycling Act sets forth very comprehensive requirements for handling of solid and hazardous wastes. The generation of electricity produces non-hazardous and hazardous materials, and we incur substantial costs to store and dispose of waste materials from our facilities. The EPA may develop new regulations that impose additional requirements on facilities that store or dispose of fossil fuel combustion materials, including types of coal ash. If so, we may be required to change the current waste management practices at some facilities and incur additional costs for increased waste management requirements.

Additionally, the Federal Comprehensive Environmental Response, Compensation and Liability Act, known as the Superfund, establishes a framework for dealing with the cleanup of contaminated sites. Many states have enacted state superfund statutes. Some of the landfills that are used for the disposal of ash may be subject to these regulations.

Current Enforcement Issues: In 1999, the DOJ on behalf of the EPA commenced enforcement actions against the power generation industry for alleged violations of the new source review regulations promulgated under the Clean Air Act (“NSR”), which require permitting and other requirements for maintenance, repairs and replacement work on plants. This action ultimately came to encompass the vast

majority of coal fired plants, with litigation against many of the largest utilities. These enforcement actions concern maintenance, repair and replacement work (“MRR work”) at power plants that the EPA alleges violated permitting and other requirements under the NSR law, which, among other things, could require the installation of emission controls at a significant cost. As a general proposition, the power generation industry disagrees with the EPA’s positions in the lawsuits and contends that this work was “routine” and exempt from the permit requirement. In 2003, there were two trial court decisions that most directly addressed the issue of whether certain MRR work triggers permitting and other NSR requirements, and the courts are split on the issue.

To date, no lawsuits or administrative actions alleging similar NSR violations have been brought by the EPA against us or our power plants. However, in 2001 the EPA requested information concerning some of our Mid-Atlantic plants covering a time period that predates our ownership and leases.

In addition, there were two regulatory developments concerning NSR in 2003 that will affect the EPA’s application of NSR in the future and, potentially, the NSR enforcement actions. In a new NSR rule, the EPA promulgated an exemption from NSR for MRR work that does not exceed 20% of the replacement value of a unit, which is generally consistent with power plant MRR work practices. In the rulemaking, the EPA also announced a policy of interpreting NSR in a way that seems generally consistent with reasonable industry practices. The new rule is being challenged in federal court and has been stayed pending judicial review, and, most recently, the EPA has announced that it is reconsidering the rule. It is unclear whether this rule will be changed or what effect these developments will have on the EPA’s NSR enforcement action.

In 2000, the State of New York issued a notice of violation (“NOV”) to the previous owner of our Lovett facility alleging NSR violations associated with the operation of that plant prior to its acquisition by us. On June 11, 2003, we and the State of New York entered into a consent decree that releases us from all potential liability for matters addressed in the NOV previously issued by the State to the prior owner. The consent decree also releases us for any other potential violation of NSR or related New York air laws prior to and through the date of entry of the consent decree by the court.

Under the decree we committed to install comprehensive emissions reduction technology on Lovett’s two coal-fired units by 2007 to 2008. The consent decree also allows us to shut down or convert one of the units to burning natural gas only rather than install the prescribed emission controls on the unit.

We cannot provide assurance that lawsuits or other administrative actions against the power plants under NSR will not be filed or taken in the future. If an action is filed against us or our power plants and we are judged to not be in compliance, we could be required to make substantial expenditures to bring the power plants into compliance, which could have a material adverse effect on our financial condition, results of operations or cash flows.

International

Some of our international operations are subject to comprehensive environmental regulations similar to those in the United States, and these regulations are expected to become more stringent in the future. Additionally, other countries in which our subsidiaries have operations, such as Trinidad and Jamaica, are developing increased environmental regulation of many industrial activities, including increased regulation of air quality, water quality and solid waste management.

Over the past several years, federal, state and foreign governments and international organizations have debated the issue of global climate change and policies regarding the regulation of greenhouse gases (“GHGs”), one of which is carbon dioxide emitted from the combustion of fossil fuels by sources such as vehicles and power plants. Recently, the European Union and certain developed countries ratified the Kyoto Protocol, an international treaty regulating GHGs, and it became effective on February 16, 2005. The current U.S. administration is opposed to the treaty, and the United States has not ratified, and is not expected to ratify, the treaty. Therefore, the treaty does not bind the United States. None of the countries

in which we or our subsidiaries presently own or operate power plants has any binding obligations under the treaty. The Commonwealth of Massachusetts has promulgated carbon dioxide (“CO2”) emission standards for certain power plants, as discussed above in this section. We cannot provide assurances that such laws or regulations will not be enacted in the future in a state or country in which we own or operate power plants, and in such event the impact on our business would be uncertain but could be material.

Employees

At December 31, 2004, our corporate offices and majority owned or controlled subsidiaries employed approximately 4,700 persons. This number includes approximately 550 employees in the corporate and North America headquarters in Atlanta, approximately 1,350 employees at operating facilities in the United States and approximately 2,800 international employees. Approximately 900 of our domestic employees are subject to collective bargaining agreements with one of the following unions: International Brotherhood of Electrical Workers, Utilities Workers of America or United Steel Workers.

Union	Location	Number of Employees Covered	Contract Expiration Date
International Brotherhood of Electrical Workers Local 1900	Maryland and Virginia	515	6/1/2010
International Brotherhood of Electrical Workers Local 503	New York	150	6/1/2008
International Brotherhood of Electrical Workers Local 1245	California	140	10/31/2005
Utility Workers of America Local 369	Cambridge, Massachusetts	30	2/28/2009
Utility Workers of America Local 480	Sandwich, Massachusetts	50	5/1/2006
United Steel Workers Local 12502	Indiana and Michigan	25	1/1/2007
Oilfield Workers’ Trade Union	Trinidad	325	12/31/2005
The Senior Staff Association	Trinidad	35	2/28/2006
Bahamas Industrial Engineers, Managerial, and Supervisory Union(1)	Grand Bahama	33	1/1/2005
Commonwealth Electrical Workers Union(2)	Grand Bahama	131	3/31/2005
Jamaica Public Service Managers’ Association(3)	Jamaica	190	11/30/2004
Union of Clerical Administrative & Supervisory Employees; National Workers Union; Bustamante Industrial Trade Union(3)	Jamaica	1,130	12/31/2004

(1) Neither side has submitted a contract proposal yet. This is not uncommon and there is no work stoppage expected.

(2) Management is currently communicating with the union to agree on a start date for negotiations. Overall, the industrial climate is stable.

(3) All unions in Jamaica were requested in writing to submit claims (proposals) prior to the expiration of the contracts. To date, only the UCASE union has submitted a claim that is being reviewed. Negotiations have not begun, as management would prefer to receive all claims prior to initiation of talks. Overall, the industrial climate is stable.

To mitigate and reduce the risk of disruption during labor negotiations, we engage in contingency planning for continuation of our generation and/or distribution activities to the extent possible during an adverse collective action by one or more of our unions. Additionally, if our non-unionized workforce moved toward unionization, we could be materially impacted through increased employee costs, work stoppages or both.

Item 2. Properties

The following properties were owned or leased as of December 31, 2004:

Operating Plants:

Power Generation Business	Location	Plant Type	Primary Fuel	Mirant’s % Leasehold/ Ownership Interest(1)		Total MW(2)		Net Equity Interest/ Lease in Total MW(2)
NORTH AMERICA
West Region:
Mirant California	California	Peaking/Intermediate	Natural Gas		100		2,347		2,347
Mirant Texas	Texas	Peaking/Baseload	Natural Gas		100		538		538
Apex	Nevada	Intermediate	Natural Gas		100		500		500
Coyote Springs(3)(4)	Oregon	Intermediate	Natural Gas/Steam		50		280		140
Mirant Wichita Falls	Texas	Peaking	Natural Gas		100		77		77
Subtotal							3,742		3,602
Northeast Region:
Mirant New England(5)	Massachusetts	Intermediate/Peaking	Natural Gas/Oil		100		1,993		1,388
Mirant New York	New York	Intermediate/Peaking/Baseload	Natural Gas/Hydro/Coal/Oil		100		1,675		1,675
Subtotal							3,668		3,063
Mid-Atlantic Region:
Mirant Mid-Atlantic	Maryland	Intermediate/Peaking/Baseload	NaturalGas/Coal/Oil		100		4,252		4,252
Mirant Peaker and Mirant Potomac River	Maryland/Virginia	Intermediate/Peaking/Baseload	NaturalGas/Coal/Oil		100		1,004		1,004
Subtotal							5,256		5,256
Mid-Continent Region:
Mirant Zeeland	Michigan	Peaking/Intermediate	Natural Gas		100		837		837
West Georgia(3)	Georgia	Peaking	Natural Gas/Oil		100		605		605
Sugar Creek	Indiana	Peaking	Natural Gas		100		535		535
Shady Hills(3)	Florida	Peaking	Natural Gas		100		468		468
Wrightsville(6)	Arkansas	Peaking/Intermediate	Natural Gas		51		438		223
Subtotal							2,883		2,668
North America Total							15,549		14,589
INTERNATIONAL
Philippines:
Sual(7)	Philippines	Baseload	Coal		94.9		1,218		1,155
Ilijan	Philippines	Baseload	Natural Gas		20		1,200		240
Pagbilao	Philippines	Baseload	Coal		95.7		735		704
Navotas II(8)	Philippines	Standby	Diesel		100		95		95
Sangi	Philippines	Baseload/Peaking/Standby	Coal/Oil		50		75		38
Panay	Philippines	Peaking/Intermediate/Baseload	Oil		50		71		35
Carmen	Philippines	Standby/Peaking	Heavy Fuel Oil		50		37		19
Avon River	Philippines	Peaking/Intermediate/Baseload	Oil		50		18		9
Mindoro	Philippines	Peaking/Intermediate/Baseload	Heavy Fuel Oil		50		6		3
Subtotal							3,455		2,298
Caribbean:
PowerGen	Trinidad & Tobago	Intermediate/Peaking/Baseload	Natural Gas		39		1,157		451
JPS	Jamaica	Intermediate/Baseload/Peaking	Oil/Hydro		80		600		480
Grand Bahama Power	Bahamas	Peaking/Intermediate/Baseload	Oil		55.4		133		74
CUC	Netherlands Antilles	Baseload/Peaking	Pitch/Refinery Gas		25.5		133		34
Subtotal							2,023		1,039
International Total							5,478		3,337
Total							21,027		17,926

Distribution Business	Location	Mirant’s % Ownership Interest			Customers/ end-users
					(in thousands)
Grand Bahama Power	Bahamas		55.4	%		18
JPS	Jamaica		80.0			540
Visayan Electric Company Inc	Philippines		1.95			273
Total						831

Other Plants:

Power Generation Business

Location

Plant Type

Primary Fuel

Mirant’s %
Leasehold/
Ownership
Interest(1)

Total
MW(2)

Net Equity
Interest/
Lease in
Total MW(2)

Bowline expansion(9)

New York

Intermediate

Natural Gas

100

750

Contra Costa expansion(9)

California

Intermediate

Natural Gas

100

580

Wyandotte(9)

Michigan

Intermediate

Natural Gas

100

560

Longview Mint Farm(9)

Washington

Intermediate

Natural Gas

100

298

Bahamas(10)

Grand Bahamas

Baseload

Diesel

55.4

Nabas(11)

Philippines

Baseload

Oil

50.0

New Washington(11)

Philippines

Baseload

Oil

50.0

(1) Amounts reflect Mirant’s percentage economic interest in the total MW.

(2) MW amounts reflect net dependable capacity.

(3) Generating plant is operated by an independent third party

(4) In October 2004, Mirant Oregon LLC (“Mirant Oregon”), our wholly-owned subsidiary, entered into an agreement to sell its 50% undivided interest in Coyote Springs 2 to Avista Energy, subject to Bankruptcy Court and regulatory approval. Mirant completed the sale in January 2005.

(5) Total MW reflects a 1.4% ownership interest, or 8.8 MW, in the 614 MW Wyman plant.

(6) Mirant temporarily shutdown this facility in January 2004. In February 2005, we entered into an agreement to sell the Wrightsville facility to AECC, subject to Bankruptcy Court approval and certain other regulatory and third-party consents and approvals. We expect the sale of the Wrightsville facility to close in 2005.

(7) Mirant acquired an additional 2.94% ownership interest in the Sual project in the first quarter of 2004, bringing its ownership interest to 94.9%.

(8) The Build-Operate-Transfer (“BOT”) agreement related to Navotas II is scheduled to expire in July 2005.

(9) Mirant does not expect to independently complete these construction projects and will either pursue partnerships to complete, sell or abandon these projects. Abandon as used in this document means ceasing to operate the affected generation asset.

(10) The Bahamas facility is scheduled to be operational in 2005.

(11) The Nabas and New Washington facilities are scheduled to be in operation by mid 2005.

We also own an oil pipeline, which is approximately 51.5 miles long and serves the Chalk Point and Morgantown generating facilities.

Item 3. Legal Proceedings

As debtors-in-possession, the Mirant Debtors are authorized under Chapter 11 to continue to operate as an ongoing business, but may not engage in transactions outside the ordinary course of business without the prior approval of the Bankruptcy Court. As of the Petition Date, most pending litigation (including some of the actions described below) is stayed, and absent further order of the Bankruptcy Court, no party, subject to certain exceptions, may take any action, again subject to certain exceptions, to recover on pre-petition claims against the Mirant Debtors. One exception to this stay of litigation is for an action or proceeding by a governmental agency to enforce its police or regulatory power. The claims asserted in litigation and proceedings to which the stay applies may be fully and finally resolved in connection with the administration of the bankruptcy proceedings and, to the extent not resolved, will need to be addressed in the Plan. On November 19, 2003, the Bankruptcy Court entered an order staying most litigation pending against current or former officers, directors and managers of the Mirant Debtors arising out of the performance of their duties and against certain potential indemnitees of the Mirant Debtors. The Bankruptcy Court took that action to avoid the risk that the continuation of such litigation would impede the Mirant Debtors’ ability to reorganize or would have a negative impact upon the assets of the Mirant Debtors. At this time, it is not possible to predict the outcome of the Chapter 11 filings or their effect on the business of the Mirant Debtors or outstanding legal proceedings. The Mirant Debtors intend to resolve as many of these claims as possible through the claims resolution process in the bankruptcy proceeding or the Plan.

California Litigation by Governmental Units and Certain Other Parties

General. The high prices for wholesale electricity and natural gas experienced in the western markets during 2000 and 2001 prompted several governmental entities to investigate the western power markets, including activities by Mirant, Mirant Americas Energy Marketing and several of Mirant Americas Generation’s wholly-owned subsidiaries. These governmental entities include the FERC, the DOJ, CPUC, the California Senate, the California State Auditor, California’s Electricity Oversight Board (the “EOB”), the General Accounting Office of the United States Congress, the San Joaquin District Attorney and the Attorney General’s offices of the States of Washington, Oregon and California. These investigations, some of which are civil and some criminal, resulted in the issuance of civil investigative demands, subpoenas, document requests, requests for admission and interrogatories directed to several Mirant entities.

General FERC Investigation. On February 13, 2002, the FERC directed its staff to undertake a fact-finding investigation into whether any entity manipulated short-term prices in electric energy or natural gas markets in the West or otherwise exercised undue influence over wholesale prices in the West, for the period January 1, 2000 and forward. On March 26, 2003, the FERC staff issued its final report regarding its investigation. Although the staff reaffirmed the FERC’s conclusion set forth in an order issued December 15, 2000 that significant supply shortfalls and a fatally flawed market design were the root causes of the problems that occurred in the California wholesale electricity market in 2000 and 2001, the staff also found that significant market manipulation had occurred in both the gas and electricity markets. The staff concluded that trading strategies of the type engaged in by Enron Corporation and its affiliates (“Enron”) as described in certain Enron memos released by the FERC in May 2002 violated provisions of the CAISO and the California Power Exchange Corporation (“Cal PX”) tariffs that prohibited gaming. It identified Mirant, without being specific as to the particular Mirant entities involved, as being one of a number of entities that had engaged in one or more of those practices. The FERC staff also found that bidding generation resources to the Cal PX and CAISO at prices unrelated to costs constituted economic withholding and violated the antigaming provisions of the CAISO and Cal PX tariffs. Mirant was one of the entities identified as engaging in that bidding practice, with the FERC staff again not being specific as to the Mirant entities involved.

On March 26, 2003, the FERC staff issued a separate report addressing allegations of physical withholding by Mirant and four other out of state owners of generation assets in California made by the CPUC in reports issued in September 2002 and January 2003. The CPUC asserted that on days in the fall of 2000 through the spring of 2001 during which the CAISO had to declare a system emergency requiring interruption of interruptible load or imposition of rolling blackouts, Mirant and four other out of state owners of generation assets in California had generating capacity that either was not operated or was out of service due to an outage and that could have avoided the problem if operated. The CPUC reports identified the Mirant entity discussed in the reports as Mirant Americas Energy Marketing, although Mirant’s generating facilities in California are owned by subsidiaries of Mirant Americas Generation. The FERC staff concluded that the CPUC’s contention that thirty-eight service interruptions could have been avoided had those five generators produced all of their available power was not supported by the evidence. The staff also indicated, however, that the FERC was continuing to investigate whether withholding by generators had occurred during 2000 and 2001.

As discussed below under “California Settlement,” on January 14, 2005, Mirant and certain of its subsidiaries entered into a Settlement and Release of Claims Agreement (the “California Settlement”) with Pacific Gas and Electric Company (“PG&E”), Southern California Edison Company (“SCE”), San Diego Gas and Electric Company, the CPUC, the California Department of Water Resources (“DWR”), the EOB and the Attorney General of the State of California (collectively, the “California Parties”) and with the Office of Market Oversight and Investigations of the FERC. If the California Settlement becomes effective, it will result in the termination of the FERC’s investigation of potential withholding by generators (the “FERC Withholding Investigation”) as to Mirant and its subsidiaries.

FERC Bidding Investigation. On June 25, 2003, the FERC issued an order (the “Bidding Order”) initiating an investigation by its staff into bidding practices in the Cal PX and CAISO markets between May 1, 2000 and October 1, 2000 of more than 50 parties, including Mirant Americas Energy Marketing. The entities subject to investigation under the Bidding Order were previously identified in the report issued by the FERC staff on March 26, 2003 as having bid generation resources to the Cal PX and CAISO at prices unrelated to costs. The Bidding Order requires those entities, including Mirant Americas Energy Marketing, to demonstrate why bids in the Cal PX and CAISO markets from May 1, 2000 through October 1, 2000 that were in excess of $250 per MWh did not constitute a violation of the CAISO and Cal PX tariffs.

As discussed below under “California Settlement,” if the California Settlement becomes effective, it will result in the termination of the FERC’s investigation under the Bidding Order of Mirant Americas Energy Marketing’s bidding practices.

FERC Show Cause Proceeding Relating to Trading Practices. On June 25, 2003, the FERC issued a show cause order (the “Trading Practices Order”) to more than 50 parties, including Mirant Americas Energy Marketing and subsidiaries of Mirant Americas Generation, that the FERC staff report issued on March 26, 2003 identified as having potentially engaged in one or more trading strategies of the type employed by Enron, as described in the Enron memos released by the FERC in May 2002. The Trading Practices Order identified certain specific trading practices that the FERC indicated could constitute gaming or anomalous market behavior in violation of the CAISO and Cal PX tariffs. The Trading Practices Order requires the CAISO to identify transactions between January 1, 2000 and June 20, 2001 that may involve the identified trading strategies, and then requires the applicable sellers involved in those transactions to demonstrate why such transactions were not violations of the CAISO and Cal PX Tariffs. On September 30, 2003, the Mirant entities filed with the FERC for approval of a settlement agreement (the “Trading Settlement Agreement”) entered into between certain Mirant entities and the FERC Trial Staff, under which Mirant Americas Energy Marketing would pay $332,411 to settle the trading practices proceeding, but did not admit any wrongdoing.

In a November 14, 2003 order in a different proceeding, the FERC ruled that certain allegations of improper trading conduct with respect to the selling of ancillary services during 2000 also should be resolved in the show cause proceeding. On December 19, 2003, the Mirant entities filed with the FERC for approval of an amendment to the Trading Settlement Agreement reached with the FERC Trial Staff with respect to the sale of ancillary services. Under the proposed amendment, the FERC would have an allowed unsecured claim in Mirant Americas Energy Marketing’s bankruptcy proceeding for $3.67 million in settlement of the allegations with respect to the sale of ancillary services (the “Ancillary Amount”).

The Trading Settlement Agreement and its amendment must be approved by the FERC and the Bankruptcy Court to become effective. The Mirant entities are in the process of obtaining FERC approval and will seek approval from the Bankruptcy Court thereafter. On March 11, 2004, a FERC administrative law judge (the “ALJ”) recommended that the FERC approve the Trading Settlement Agreement, finding that the settlement amounts were reasonable. The ALJ, however, suggested that approval of the settlement be conditioned on the Ancillary Amount being treated as an administrative claim or a setoff rather than as an allowed pre-petition claim. If the Ancillary Amount were to be treated as an administrative claim, that amount would receive priority status in the payment of claims against Mirant Americas Energy Marketing in the bankruptcy proceedings.

As discussed below under “California Settlement,” if the California Settlement becomes effective, it will result in the California Parties withdrawing their opposition to the Trading Settlement Agreement as amended and supporting approval of the Trading Settlement Agreement as proposed by Mirant and the FERC Trial Staff without change or modification.

California Receivables. In 2001, SCE and PG&E suspended payments to the Cal PX and the CAISO for certain power purchases, including purchases from Mirant Americas Energy Marketing. Both the Cal PX and PG&E filed for bankruptcy protection in 2001. As discussed below under “California Settlement,” if the California Settlement becomes effective, it will result in Mirant Americas Energy Marketing assigning to the California Parties its outstanding receivables for sales made in the Cal PX and CAISO markets from January 1, 2000 through June 20, 2001.

FERC Refund Proceedings. As a result of the increase in electricity prices in 2000 and 2001, the California Parties have pursued litigation at the FERC, claiming that the prices charged by Mirant Americas Energy Marketing and other market participants in the California energy markets during certain periods in 2000 and 2001 were excessive. In July 2001, the FERC issued an order requiring proceedings (the “FERC Refund Proceedings”) to determine the amount of any refunds and amounts owed for sales made to the CAISO or the Cal PX from October 2, 2000 through June 20, 2001 (the “Refund Period”). Various parties have appealed these FERC orders to the United States Court of Appeals for the Ninth Circuit (the “Ninth Circuit”) seeking review of a number of issues, including changing the Refund Period to include periods prior to October 2, 2000 and expanding the sales of electricity subject to potential refund to include bilateral sales made to the DWR. Any such expansion of the Refund Period or the types of sales of electricity potentially subject to refund could significantly increase the refund exposure of Mirant Americas Energy Marketing in this proceeding. Although Mirant Americas Energy Marketing is the Mirant entity that engaged in transactions with the CAISO and the Cal PX, the orders issued by the FERC in the refund proceedings, and the filings made by other parties in those proceedings, generally refer to the Mirant entity involved as Mirant without being more specific. Mirant believes that the Mirant entity that would actually be liable to third parties for any refunds determined by the FERC to be owed, or that would be due any receivables found to be owed to Mirant, is Mirant Americas Energy Marketing. Agreements that were in effect at the time of the transactions at issue between Mirant Americas Energy Marketing and the Mirant Americas Generation subsidiaries that own Mirant’s generating facilities in California would shift some of the economic burden of such refunds or the benefit of such receivables from Mirant Americas Energy Marketing to those Mirant Americas Generation subsidiaries.

On December 12, 2002, a FERC ALJ determined the preliminary amounts owed to and by each entity acting as a scheduling coordinator in the CAISO and Cal PX markets, including Mirant Americas Energy Marketing. Based on the ALJ’s determination, the initial amounts owed to Mirant Americas Energy Marketing totaled approximately $122 million, which is net of refunds owed by Mirant Americas Energy Marketing to the CAISO and the Cal PX. The ALJ decision indicated that these amounts did not reflect the final mitigated market clearing prices, interest that would be applied under the FERC’s regulations, offsets for emission costs or the effect of certain findings made by the ALJ in the initial decision. A December 2002 errata issued by the ALJ to his initial decision indicated that the amounts identified by the initial decision as being owed to Mirant Americas Energy Marketing and other participants in the Cal PX market failed to reflect an adjustment for January 2001 that the ALJ concluded elsewhere in his initial decision should be applied. If that adjustment is applied, the amount owed Mirant Americas Energy Marketing by the Cal PX, and the net amount owed Mirant Americas Energy Marketing by the CAISO and the Cal PX after taking into account the proposed refunds, would increase by approximately $37 million.

On March 26, 2003, the FERC largely adopted the findings the ALJ made in his December 12, 2002 order with the exception that the FERC concluded that the price of gas used in calculating the mitigated market prices used to determine refunds should not be based on published price indices. Instead, the FERC ruled that the price of gas should be based upon the price at the producing area plus transportation costs. This adjustment by the FERC to the refund methodology is expected to increase the refunds owed by Mirant Americas Energy Marketing and therefore to reduce the net amount that would remain owed to Mirant Americas Energy Marketing from the CAISO and Cal PX after taking into account any refunds. Based solely on the staff’s formula, the amount of the reduction could be as much as approximately $110 million, which would reduce the net amount owed to Mirant Americas Energy Marketing by the CAISO and Cal PX to approximately $49 million. The FERC indicated that it would allow any generator that could demonstrate it actually paid a higher price for gas to recover the differential between that higher price and the proxy price for gas adopted by the FERC. Mirant Americas Energy Marketing has filed information with the FERC indicating that its actual cost of gas used to make spot sales of electricity was higher than the amounts calculated under the staff’s formula, which, if accepted, would decrease significantly the $110 million and increase the resulting net amount owed to Mirant Americas Energy Marketing, although the amount of such potential decrease that will be accepted by the FERC and the resulting net amount owed to Mirant Americas Energy Marketing cannot at this time be determined. On October 16, 2003, the FERC issued an order addressing motions for rehearing filed with respect to its March 26, 2003 order, and in that October 16, 2003 order the FERC changed how certain power sales made to the CAISO were to be treated. Mirant Americas Energy Marketing estimates that the effect of the October 16, 2003 order will be to decrease the refunds owed by Mirant Americas Energy Marketing, and therefore to increase the net amounts owed to Mirant Americas Energy Marketing, by $27 million. On May 12, 2004, the FERC issued an order on rehearing of the October 16, 2003 order that further modified how certain power sales made to the CAISO are to be treated and that may reduce significantly the potential benefit to Mirant Americas Energy Marketing of the October 16, 2003 order. In another order issued May 12, 2004, the FERC also further refined the methodology to be used to determine the costs of gas that a generator can recover where it can demonstrate that it paid a higher price for gas than the proxy price for gas previously adopted by the FERC in its March 23, 2003 order, and those changes may have the effect of reducing the costs that Mirant Americas Energy Marketing is able to recover. Mirant Americas Energy Marketing sought rehearing of the May 12, 2004 order, but the FERC denied that request for rehearing on September 24, 2004. Mirant Americas Energy Marketing is unable at this time to quantify further the impact of the May 12, 2004 orders.

The amount owed to Mirant Americas Energy Marketing from sales made to either the CAISO or the Cal PX, the amount of any refund that Mirant Americas Energy Marketing might be determined to owe the CAISO or the Cal PX, and whether Mirant Americas Energy Marketing may have any refund obligation to the DWR may be affected materially by the ultimate resolution of the issues described above related to which gas indices should be used in calculating the mitigated market clearing prices, allegations of market manipulation, whether the Refund Period should include periods prior to October 2, 2000, and whether the sales of electricity potentially subject to refund should include sales made to the DWR. In addition, in the Chapter 11 proceedings the Mirant Debtors initiated adversary actions against PG&E, SCE, the CAISO, the Cal PX, and the DWR seeking a determination that the Bankruptcy Code prohibits the offsetting of any refunds that Mirant Americas Energy Marketing is found to owe by the FERC in the FERC Refund Proceedings against amounts owed to Mirant Americas Energy Marketing for sales made into the CAISO and Cal PX markets.

In the July 25, 2001 order, the FERC also ordered that a preliminary evidentiary proceeding be held to develop a factual record on whether there had been unjust and unreasonable charges for spot market bilateral sales in the Pacific Northwest from December 25, 2000 through June 20, 2001. In the proceeding, the California Attorney General, the CPUC and the EOB filed to recover certain refunds from parties, including Mirant Americas Energy Marketing, for bilateral sales of electricity to the DWR at the California/Oregon border, claiming that such sales took place in the Pacific Northwest. The refunds sought from Mirant Americas Energy Marketing totaled approximately $90 million. If Mirant Americas Energy Marketing were required to refund such amounts, subsidiaries of Mirant Americas Generation could be required under inter-company agreements with Mirant Americas Energy Marketing to refund amounts previously received from Mirant Americas Energy Marketing pursuant to sales made on their behalf during the refund period. In addition, those Mirant Americas Generation subsidiaries would be owed amounts for refunds received by Mirant Americas Energy Marketing related to purchases made on their behalf by Mirant Americas Energy Marketing from other sellers in the Pacific Northwest. In an order issued June 25, 2003, the FERC ruled that no refunds were owed and terminated the proceeding. On November 10, 2003, the FERC denied requests for rehearing filed by various parties. Various parties have appealed the FERC’s decision to the Ninth Circuit.

On September 9, 2004, the Ninth Circuit reversed the FERC’s dismissal of a complaint filed in 2002 by the California Attorney General that sought refunds for transactions conducted in markets administered by the CAISO and the Cal PX outside the Refund Period set by the FERC and for transactions between the DWR and various owners of generation and power marketers, including Mirant Americas Energy Marketing and subsidiaries of Mirant Americas Generation. The Ninth Circuit remanded the proceeding to the FERC for it to determine what remedies, including potential refunds, are appropriate where entities, including Mirant Americas Energy Marketing, purportedly did not comply with certain filing requirements for transactions conducted under market-based rate tariffs. Mirant Americas Energy Marketing and other parties have filed a motion for rehearing of the Ninth Circuit’s decision.

As discussed below under “California Settlement,” the California Settlement, once effective, will result in the release of most of Mirant Americas Energy Marketing’s potential liability in the FERC Refund Proceedings and the other FERC proceedings described in this section. Under the California Settlement, the California Parties will release Mirant and its subsidiaries from any liability to the California Parties related to sales of electricity and natural gas in the western markets from January 1, 1998 through July 14, 2003, including any claims for refunds in the FERC Refund Proceedings or in any proceedings conducted by FERC as a result of the Ninth Circuit’s ruling with respect to the complaint filed by the California Attorney General. Also, the California Parties will assume the obligation of Mirant Americas Energy Marketing to pay any refunds determined by the FERC to be owed by Mirant Americas Energy Marketing to other parties for transactions in the CAISO and Cal PX markets during the Refund Period. Some of the consideration to be received by the California Parties under the settlement will be available to

other market participants that choose to opt into the settlement. Any market participant that elects to opt into the settlement will give releases of liability to Mirant Americas Energy Marketing that are the same as those given by the California Parties. Subject to applicable bankruptcy law, however, Mirant Americas Energy Marketing will continue to be liable for any refunds that FERC determines it to owe (1) to participants in the Cal PX and CAISO markets that are not California Parties (or that do not elect to opt into the settlement) for periods outside of the Refund Period and (2) to participants in bilateral transactions with Mirant Americas Energy Marketing that are not California Parties (or that do not elect to opt into the settlement).

DWR Power Purchases Proceeding. On May 22, 2001, Mirant Americas Energy Marketing entered into a 19-month agreement with the DWR to provide the State of California with approximately 500 MW of electricity during peak hours through December 31, 2002 (the “DWR Contract”). On February 25, 2002, the CPUC and the EOB filed separate complaints at the FERC against Mirant Americas Energy Marketing and other sellers of electricity under long term agreements with the DWR, alleging that the terms of these contracts were unjust and unreasonable and that the contracts should be abrogated or the prices under the contracts should be reduced. The complaints allege that the prices the DWR was forced to pay pursuant to these long-term contracts were unreasonable due to dysfunctions in the California market and the alleged market power of the sellers. Under inter-company agreements, subsidiaries of Mirant Americas Generation bear the risk of any abrogation of or revision to the terms of the May 22, 2001 contract between Mirant Americas Energy Marketing and the DWR. On June 26, 2003, the FERC issued an order dismissing the complaints filed by the CPUC and the EOB against Mirant Americas Energy Marketing. On November 10, 2003, the FERC denied motions for rehearing filed by the CPUC and the EOB. The CPUC and EOB have appealed the FERC’s decision to the Ninth Circuit.

As discussed below under “California Settlement,” if the California Settlement becomes effective, it will result in the release of Mirant Americas Energy Marketing by the DWR and the other California Parties of any liability with respect to the DWR Contract and the dismissal by the CPUC and the EOB of their appeal of the FERC’s decision dismissing their complaints.

Reliability Must Run Agreements Proceeding. Certain of the generating facilities acquired by subsidiaries of Mirant Americas Generation from PG&E are operated subject to reliability-must-run agreements (“RMR Agreements”), which those subsidiaries assumed from PG&E. These agreements allow the CAISO to require the Mirant Americas Generation subsidiaries, under certain conditions, to operate these facilities to support the California electric transmission system. The rates that the Mirant Americas Generation subsidiaries could charge the CAISO under those agreements, where they were also making sales into the market and were retaining the revenues from those sales, were the subject of an ongoing disputed rate proceeding before the FERC at the time of the acquisition of the plants from PG&E and were being collected subject to refund. For the plants that are subject to the RMR Agreements and from which the Mirant Americas Generation subsidiaries have exercised their rights to also make market sales, the Mirant Americas Generation subsidiaries have been collecting from the CAISO since April 1999 an amount equal to 50% of the annual fixed revenue requirement (the “Annual Requirement”) of those plants. The amounts the Mirant Americas Generation subsidiaries collect from the CAISO are subject to refund pending final review and approval by the FERC. While the CAISO is the party to the RMR Agreements with the Mirant Americas Generation subsidiaries, the CAISO’s obligations under those agreements are funded by PG&E and PG&E is the real party in interest with respect to any refunds owed by the Mirant Americas Generation subsidiaries for sales made previously under those agreements. In June 2000, the ALJ issued a decision finding that the amount the Mirant Americas Generation subsidiaries should be allowed to charge the CAISO for such plants was approximately 3½% on average of the Annual Requirement. In July 2000, the Mirant Americas Generation subsidiaries sought review by the FERC of the ALJ decision, and a decision is pending at the FERC.

The Mirant Americas Generation subsidiaries recognize revenue related to these agreements based on the rates ruled to be reasonable by the ALJ. If the Mirant Americas Generation subsidiaries are unsuccessful in seeking modification of the ALJ’s decision by the FERC, they will be required to refund amounts collected in excess of those rates for the period from June 1, 1999. For the Potrero plant and Pittsburg Units 1 through 4 the period for which such refunds would be owed would run through December 31, 2001, for Mirant America Generation’s other California plants except Pittsburg Unit 5 the refund period would run through December 31, 2002, and for Pittsburg Unit 5 the refund period would run through December 31, 2003. Amounts collected in excess of those rates and other significantly smaller amounts collected under the RMR Agreements that are also subject to refund due to other issues pending at the FERC totaled $293 million, of which $288 million is included in liabilities subject to compromise and $5 million is deferred and included in revenues subject to refund as of December 31, 2004 and December 31, 2003. In addition, Mirant Americas Generation records accrued interest on such amounts, which amounted to $42 million and is included in liabilities subject to compromise as of December 31, 2004 and December 31, 2003, respectively.

As discussed below under “California Settlement,” if the California Settlement becomes effective, it will result in PG&E releasing the Mirant Americas Generation subsidiaries from any potential refund liability under the RMR Agreements for the period prior to September 30, 2004 in return for certain consideration as described below. In addition, the CAISO has separately agreed with Mirant to release its claims for refunds with respect to the RMR Agreements for the period through September 30, 2004 upon the California Settlement becoming effective.

California Attorney General Litigation. On March 11, 2002, the California Attorney General filed a civil suit against Mirant, Mirant Americas, Inc., Mirant Americas Energy Marketing and several Mirant Americas Generation subsidiaries (the “Mirant Defendants”). The lawsuit alleges that, between 1998 and 2001, the Mirant Defendants effectively double-sold capacity by selling both ancillary services and energy from the same generating units in violation of the CAISO tariff and the California Unfair Competition Act. The suit seeks both restitution and penalties in unspecified amounts. The Mirant Defendants removed this suit from the state court in which it was originally filed to the United States District Court for the Northern District of California. The district court, on March 25, 2003, granted the Mirant Defendants’ motion seeking dismissal of this suit. The California Attorney General appealed that dismissal to the Ninth Circuit. On July 6, 2004, the Ninth Circuit affirmed the dismissal of the suit by the district court. On July 27, 2004, the California Attorney General filed a petition with the Ninth Circuit seeking rehearing of the July 6, 2004 decision, and the Ninth Circuit denied that request on October 29, 2004. On January 27, 2005, the California Attorney General filed a petition for writ of certiorari with the United States Supreme Court seeking to appeal the Ninth Circuit’s decision.

On March 20, 2002, the California Attorney General filed a complaint with the FERC against certain power marketers and their affiliates, including Mirant Americas Energy Marketing and subsidiaries of Mirant Americas Generation, alleging that market based sales of energy made by such generators to the CAISO and the Cal PX and in bilateral transactions with the DWR were in violation of the Federal Power Act in part because such transactions were not filed appropriately with the FERC. The complaint requests, among other things, refunds for any prior short-term sales of energy that are found not to be just and reasonable along with interest on any such refunded amounts. The FERC dismissed the California Attorney General’s complaint and denied the California Attorney General’s request for rehearing. On September 9, 2004, the Ninth Circuit reversed the FERC’s dismissal of the California Attorney General’s complaint and remanded the case back to the FERC for further proceedings. The Ninth Circuit found that while the FERC has the authority to allow market based rates, the alleged failure of certain entities selling electric energy at market-based rates, including the Mirant parties, to comply with reporting regulations established by the FERC for entities with authority to sell at market-based rates was more than a technical compliance issue as the FERC had found. Mirant Americas Energy Marketing and other parties have filed

a petition with the Ninth Circuit seeking rehearing of the September 9, 2004 ruling. This ruling could result in the expansion of the Refund Period to include dates from January 1, 2000 through June 20, 2001, and could result in refunds being ordered for transactions outside the CAISO and Cal PX markets.

On April 9, 2002, the California Attorney General filed a second civil suit against the Mirant Defendants. That lawsuit alleges that the Mirant Defendants violated the California Unfair Competition Act by failing to properly file their rates, prices, and charges with the FERC as required by the Federal Power Act, and by charging unjust and unreasonable prices in violation of the Federal Power Act. The complaint seeks unspecified penalties, costs and attorney fees. The Mirant Defendants removed this suit from the state court in which it was originally filed to the United States District Court for the Northern District of California. The district court, on March 25, 2003, granted the Mirant Defendant’s motion seeking dismissal of this suit. On October 12, 2004, the Ninth Circuit affirmed the district court’s dismissal of the suit.

On April 15, 2002, the California Attorney General filed a third civil lawsuit against the Mirant Defendants in the United States District Court for the Northern District of California. The lawsuit alleges that the acquisition and possession of the Potrero and Delta power plants by subsidiaries of Mirant Americas Generation has substantially lessened, and will continue to substantially lessen, competition in violation of the Clayton Act of 1914, as amended (the “Clayton Act”) and the California Unfair Competition Act. The lawsuit seeks equitable remedies in the form of divestiture of the plants and injunctive relief, as well as monetary damages in unspecified amounts to include disgorgement of profits, restitution, treble damages, statutory civil penalties and attorney fees. On March 25, 2003, the court dismissed the California Attorney General’s state law claims and his claim for damages under the Clayton Act, but did not dismiss the California Attorney General’s claims for divestiture. On December 3, 2003, the district court stayed the suit during the pendency of the Company’s bankruptcy proceedings. The California Attorney General appealed that ruling to the Ninth Circuit, and on February 10, 2005, the Ninth Circuit vacated the stay and remanded the proceeding to the district court.

On August 18, 2004, the California Attorney General filed a fourth civil suit in the Superior Court of California, San Francisco County, against the Mirant Defendants. The suit asserts claims under the California Unfair Competition Act and the California Commodity Law of 1990. The California Attorney General alleges that beginning in 1999 and continuing through 2001, the Mirant Defendants engaged in manipulative and fraudulent schemes in the California wholesale electricity markets, including allegedly obtaining congestion relief payments for actions that did not relieve any congestion, receiving payment for excessive generation through the submission of false schedules, circumventing price caps by falsely representing the source of energy, receiving payment for ancillary services they did not and could not provide, and falsely reporting generating units as unavailable to produce electricity when they were available. The suit seeks damages, restitution, disgorgement of profits, civil penalties and injunctive relief. The Mirant Defendants have removed the suit to the United States District Court for the Northern District of California and have filed a motion seeking dismissal of the claims asserted on the grounds that they are barred by the doctrine of preemption and the filed rate doctrine.

As discussed below under “California Settlement,” if the California Settlement becomes effective, the California Attorney General will dismiss with prejudice the four civil suits described above and will release all claims against Mirant entities asserted in the complaint filed with the FERC on March 20, 2002 described above.

California-Related Claims in the Bankruptcy Proceedings. Various entities have filed proofs of claim in bankruptcy proceedings in undetermined amounts against Mirant, Mirant Americas Energy Marketing, Mirant Americas Generation and other Mirant subsidiaries on account of the various proceedings described above. Those entities include the California Attorney General, the DWR, the CPUC, PG&E, SCE, San Diego Gas & Electric Company, the Cal PX and the CAISO. In addition, the FERC has filed

proofs of claim concerning the FERC Refund Proceedings, the proceedings related to the RMR Agreements and the proceedings and investigations described above in “General FERC Investigation,” “FERC Bidding Investigation” and “FERC Show Cause Proceeding Related to Trading Practices.” Some of these claims also assert a right to set off the amount of any refunds owed by Mirant Americas Energy Marketing to the claimant against any amounts owed by such claimant to Mirant Americas Energy Marketing.

As discussed below under “California Settlement,” if the California Settlement becomes effective, it will result in the withdrawal with prejudice of the claims filed in the bankruptcy proceedings by the California Attorney General, the DWR, the CPUC, PG&E, SCE and San Diego Gas & Electric Company in return for the specific allowed claims and other consideration provided for in the California Settlement. Also, although the California Settlement will not result in the withdrawal of the claims filed by the CAISO or the Cal PX, under its terms the FERC’s approval of the settlement will constitute its direction to the CAISO and Cal PX to conform their books and records to the terms of the California Settlement and to withdraw with prejudice all claims filed by them in the bankruptcy proceedings that seek to recover amounts or otherwise obtain relief on behalf of or for the benefit of any of the California Parties. In addition, the CAISO has separately agreed with Mirant to release its claims upon the California Settlement becoming effective.

California Settlement. On January 14, 2005, Mirant and certain of its subsidiaries entered into the California Settlement with the California Parties and the Office of Market Oversight and Investigations of the FERC settling a variety of disputed matters described above. The Mirant entities that are parties to the California Settlement are Mirant, Mirant Americas Inc., Mirant Americas Energy Marketing, Mirant Americas Generation, Mirant California Investments, Inc., Mirant California, LLC, Mirant Delta, LLC, Mirant Potrero, LLC, Mirant Special Procurement, Inc., Mirant Services, LLC and Mirant Americas Development, Inc. (collectively, the “Mirant Settling Parties”). The California Parties are PG&E, Southern California Edison Company, San Diego Gas and Electric Company, the CPUC, the DWR, the EOB and the Attorney General of the State of California. The effectiveness of the California Settlement is conditioned upon its approval by the CPUC, the Bankruptcy Court, the bankruptcy court having jurisdiction over PG&E’s bankruptcy proceedings initiated in 2001, and the FERC. While CPUC has approved the California Settlement, as signified by its execution of the California Settlement, the other approvals have not yet been obtained.

If the California Settlement becomes effective, (1) Mirant Americas Energy Marketing and the other Mirant Settling Parties will assign to the California Parties all receivables owed to Mirant Americas Energy Marketing for transactions in the markets administered by the Cal PX or the CAISO for the period January 1, 2000 through June 20, 2001, which are currently estimated by the parties to the California Settlement to be approximately $283 million, and (2) the California Parties will receive an allowed, unsecured claim against Mirant Americas Energy Marketing in its Chapter 11 case for $175 million and the DWR will receive an additional allowed, unsecured claim against Mirant Americas Energy Marketing of $2.25 million. In return, the California Parties will release all claims they may have against the Mirant Settling Parties related to sales of electricity or natural gas at wholesale in western markets in the period from January 1, 1998 through July 14, 2003, including all such claims filed by the California Parties in the Mirant Debtors’ Chapter 11 cases, in proceedings currently pending before the FERC, or in the four pending suits filed by the California Attorney General. Mirant estimates that, excluding duplicative claims, this settlement will compromise the bulk of the California energy market claims at issue in the FERC Refund Proceedings. Also, the California Parties will assume Mirant Americas Energy Marketing’s obligation to pay any refunds determined by the FERC to be owed by Mirant Americas Energy Marketing to other parties for transactions in the CAISO and Cal PX markets during the Refund Period. Subject to applicable bankruptcy law, Mirant Americas Energy Marketing will continue to be liable for any refunds that the FERC determines it to owe to (1) participants in the Cal PX or CAISO markets other than the

California Parties for periods outside the Refund Period or (2) parties with which Mirant Americas Energy Marketing engaged in bilateral electricity or natural gas transactions other than the California Parties.

Some of the consideration to be received by the California Parties under the California Settlement will be available to other market participants that choose to opt into the California Settlement. Any market participant that elects to opt into the California Settlement will give releases of liability to the Mirant Settling Parties that are the same as those given by the California Parties. In addition to the claims filed by the California Parties seeking to recover refunds from Mirant Americas Energy Marketing and other Mirant entities for sales of electricity made by Mirant Americas Energy Marketing into the CAISO and Cal PX markets in 2000 and 2001, the CAISO and the Cal PX have filed claims against Mirant Americas Energy Marketing and other Mirant Settling Parties seeking to recover refunds on behalf of participants in the markets for which they were responsible. While the California Settlement will not result in the withdrawal of the claims filed in the Chapter 11 cases by the CAISO or the Cal PX, the FERC’s approval of the California Settlement (if obtained) will, upon the California Settlement becoming effective, constitute the FERC’s direction to the CAISO and the Cal PX to conform their books and records to the terms of the settlement and to withdraw with prejudice all claims filed by them in the Chapter 11 cases that seek to recover amounts or otherwise obtain relief on behalf of, or for the benefit of, any of the California Parties or any other market participants that opt into the California Settlement. In addition, the CAISO has separately agreed with Mirant to release its claims upon the California Settlement becoming effective. The California Parties also release the Mirant Settling Parties from any liability or refund claims related to the DWR Contract, including claims asserted in complaints filed by CPUC and EOB with the FERC in February 2002. The FERC’s approval of the California Settlement, under its terms, will also have the effect, once the California Settlement becomes effective, of terminating any pending investigations by the FERC of the conduct of the Mirant Settling Parties in the western energy markets in 2000 and 2001, including pending investigations pursuant to the Bidding Order or the FERC Withholding Investigation.

The California Settlement will also resolve all claims asserted by PG&E against Mirant Delta, Mirant Potrero, and the other Mirant Settling Parties in the Chapter 11 cases or in proceedings before the FERC that relate to refunds potentially owed as described under “Reliability-Must-Run Agreements Proceeding” above. Under the California Settlement, PG&E will release Mirant Delta and Mirant Potrero from any potential refund liability under the RMR Agreements for the period prior to September 30, 2004, and the claims filed by PG&E in the Chapter 11 cases seeking to recover refunds from Mirant Delta and Mirant Potrero for sales made under the RMR Agreements will be withdrawn with prejudice. Although the California Settlement will not result in the withdrawal of the claims filed in the Chapter 11 cases by the CAISO, under the terms of the California Settlement, the FERC’s approval of the California Settlement will constitute its direction to CAISO to conform its books and records to the terms of the California Settlement and to withdraw with prejudice all claims filed by it in the Chapter 11 cases that seek to recover amounts related to sales made under the RMR Agreements in the period prior to September 30, 2004. In addition, the CAISO has separately agreed with Mirant to release its claims upon the California Settlement becoming effective.

In return for the releases it grants to the Mirant Settling Parties described in the previous paragraph, PG&E will receive allowed, unsecured claims against Mirant Delta that will receive a distribution of proceeds of $63 million, and either (1) the partially constructed Contra Costa 8 project, which is a planned 530 MW combined cycle generating facility, and related equipment (collectively, the “CC8 Assets”) will be transferred to PG&E or (2) PG&E will receive additional alternative consideration in an amount of as much as $85 million (the “CC8 Alternative Consideration”). If the Mirant Settling Parties and PG&E are unable by April 30, 2005 to agree upon definitive agreements for the transfer of the CC8 Assets to PG&E, or if any approval of the Bankruptcy Court required for the transfer of the CC8 Assets to PG&E is not obtained, the CC8 Alternative Consideration is to be $85 million. Once such definitive agreements have been executed and any such required approval by the Bankruptcy Court of the transfer of the CC8 Assets has been obtained, the CC8 Alternative Consideration is reduced to $70 million.

To fund the CC8 Alternative Consideration, PG&E will receive an allowed, unsecured claim against Mirant Delta that will receive a distribution of either $85 million or $70 million depending on the maximum CC8 Alternative Consideration at the time of such distribution. PG&E will liquidate any securities received as part of such distribution and place the net resulting amount plus any cash received into an escrow account. To the extent that the net amount resulting from the liquidation of the securities received by PG&E plus any cash received by it is less than the CC8 Alternative Consideration, the difference will be made up by PG&E withholding and paying into the escrow account amounts it owes to Mirant Delta over a three month period under the power purchase agreement described below or by payments from Mirant Delta or Mirant Americas Generation. If the transfer of the CC8 Assets to PG&E does not occur on or before June 30, 2008, or if certain specified events occur prior to that date, such as the failure of the Mirant Settling Parties and PG&E to execute definitive agreements for the transfer of the CC8 Assets or the CPUC fails to approve PG&E’s acquisition of the CC8 Assets, then the CC8 Alternative Consideration is to be paid to PG&E and the Mirant Settling Parties will retain the CC8 Assets. If PG&E closes on its acquisition of the CC8 Assets, the funds in the escrow account will be paid to Mirant Delta.

PG&E also has entered into two power purchase agreements with Mirant Delta and Mirant Potrero that will allow PG&E to dispatch and purchase the power output of all units of the generating plants owned by those entities that have been designated by the CAISO as RMR units under the RMR Agreements. The first agreement is for 2005 and will be effective regardless of whether the California Settlement becomes effective. The second agreement will be for 2006 through 2012 and will become effective only if the California Settlement becomes effective. If the California Settlement has not become effective by January 1, 2006 and has not been terminated, the first power purchase agreement will be extended through December 31, 2006 and the second agreement will start January 1, 2007 if the settlement becomes effective.

Under the California Settlement, PG&E and Mirant Delta also are to negotiate by April 30, 2005 an agreement (the “Option Agreement”) under which PG&E would have separate options to purchase each of Mirant Delta’s existing Contra Costa generating plant and its existing Pittsburg generating plant, in both cases once no unit at the plant has operated for a certain period of years. The price at which each plant could be purchased pursuant to the option would be equal to the amount of certain capital costs not recovered by Mirant Delta under the terms of the RMR Agreement applicable to that plant at the time of the exercise of the option. If Mirant Delta and PG&E do not reach agreement on the Option Agreement by April 30, 2005, or if PG&E cannot obtain CPUC approval of the Option Agreement or its exercise of its rights thereunder, Mirant Delta and the other Mirant Settling Parties will have no further obligations to PG&E with respect to the Option Agreement or the rights it was to provide to PG&E.

Rate Payer Litigation

California Rate Payer Litigation. Various lawsuits are pending that assert claims under California law based on allegations that certain owners of electric generation facilities in California and energy marketers, including Mirant, Mirant Americas Energy Marketing and several Mirant Americas Generation subsidiaries, engaged in various unlawful and anti-competitive acts that served to manipulate wholesale power markets and inflate wholesale electricity prices in California.

Six such suits were filed between November 27, 2000 and May 2, 2001 in various California Superior Courts. Three of these suits seek class action status, while two of the suits are brought on behalf of all citizens of California. One lawsuit alleges that, as a result of the defendants’ conduct, customers paid approximately $4 billion more for electricity than they otherwise would have and seeks an award of treble damages as well as other injunctive and equitable relief. One lawsuit also names certain of Mirant’s officers individually as defendants and alleges that the state had to spend more than $6 billion purchasing

electricity. The other suits likewise seek treble damages and equitable relief. One such suit names Mirant itself as a defendant. A listing of these six cases is as follows:

Caption	Date Filed	Court of Original Filing
People of the State of California v.
Dynegy, et al.	January 18, 2001	Superior Court of California—San Francisco County
Gordon v. Reliant Energy, Inc., et al.	November 27, 2000	Superior Court of California—San Diego County
Hendricks v. Dynegy Power
Marketing, Inc., et al.	November 29, 2000	Superior Court of California—San Diego County
Sweetwater Authority, et al. v.
Dynegy, Inc., et al.	January 16, 2001	Superior Court of California—San Diego County
Pier 23 Restaurant v. PG&E Energy
Trading, et al.	January 24, 2001	Superior Court of California—San Francisco County
Bustamante, et al. v. Dynegy, Inc., et al.	May 2, 2001	Superior Court of California—Los Angeles County

These six suits (the “Six Coordinated Suits”) were coordinated for purposes of pretrial proceedings before the Superior Court for San Diego County. In the spring of 2002, two of the defendants filed crossclaims against other market participants who were not parties to the actions. Some of those crossclaim defendants then removed the Six Coordinated Suits to the United States District Court for the Southern District of California. The plaintiffs filed a motion seeking to have the actions remanded to the California state court, and the defendants filed motions seeking to have the claims dismissed. On December 13, 2002, the United States District Court for the Southern District of California granted the plaintiffs’ motion seeking to have the six cases remanded to the California state court. The defendants that filed the crossclaims appealed that decision remanding the Six Coordinated Suits to the California state courts to the Ninth Circuit. On December 8, 2004, the Ninth Circuit affirmed the district court’s remand decision. These actions are stayed with respect to the Mirant entities that are defendants by the filing of the Chapter 11 proceedings of those entities, but are proceeding with respect to the other defendants.

Two plaintiffs in the Six Coordinated Suits, Oscar’s Photo Lab and Mary L. Davis (the “Claimants”), filed proofs of claim (the “Oscar Claims”) in the bankruptcy proceedings against Mirant, Mirant Americas Energy Marketing, Mirant Americas Generation and other subsidiaries of Mirant on behalf of themselves and a purported class of all persons or entities in California who purchased electricity or natural gas for purposes other than resale or distribution at any time since January 1, 1999. Claimants alleged that various misconduct by Mirant and several of its subsidiaries caused inflated prices in the California wholesale power markets. Claimants listed the damage amount of their claims as “unliquidated.” On October 18, 2004, the Mirant Debtors filed an objection to the Oscar Claims. On November 5, 2004, the Mirant Debtors filed a motion requesting that the Bankruptcy Court strike the portions of the Oscar Claims that purported to have been filed on behalf of unnamed absent members of a purported class. On January 26, 2005, the Bankruptcy Court issued an order embodying a ruling made orally on December 1, 2004 granting this motion and disallowing the Oscar Claims with prejudice to the extent they sought to recover on account of any claims other than the claims of Oscar Photo Labs and Mary L. Davis in their individual capacities. The Claimants have filed a motion to amend their claims to add allegations of improper conduct by Mirant entities with respect to the reporting of information about natural gas transactions to trade publications that publish price indices, and the Mirant Debtors have also filed a motion to disallow the Oscar Claims. The Bankruptcy Court has not acted upon either motion.

The Mirant Debtors have entered into a stipulation with the Claimants entitling each plaintiff to receive an allowed, general, prepetition unsecured claim against Mirant Americas Energy Marketing in the amount of $1,000 without the Mirant Debtors’ admission of the validity of the Oscar Claims or any of the factual or legal assertions of these Claimants and with a full reservation of any rights, claims and defenses any of the Mirant Debtors may have against any person asserting the same or similar factual or legal assertions as those contained in the Oscar Claims. On March 9, 2005, the Bankruptcy Court entered the order and approved the stipulation.

Eight additional rate payer lawsuits were filed between April 23, 2002 and October 18, 2002 alleging that certain owners of electric generation facilities in California, as well as certain energy marketers, including Mirant, Mirant Americas Energy Marketing and several Mirant Americas Generation subsidiaries, engaged in various unlawful and fraudulent business acts that served to manipulate wholesale markets and inflate wholesale electricity prices in California during 1999 through 2002. Each of the complaints alleges violation of California’s Unfair Competition Act. One complaint also alleges violation of California’s antitrust statute. Each of the plaintiffs seeks class action status for their respective case. Some of these suits also allege that contracts between the DWR and certain marketers of electricity, including a nineteen month power sales agreement entered into by Mirant Americas Energy Marketing with the DWR in May 2001 that terminated in December 2002, contain terms that were unjust and unreasonable. The actions seek, among other things, restitution, compensatory and general damages, and to enjoin the defendants from engaging in illegal conduct. The captions of each of these eight cases follow:

Caption	Date Filed	Court of Original Filing
T&E Pastorino Nursery, et al. V. Duke Energy
Trading and Marketing, LLC, et al.	April 23, 2002	Superior Court of California—San Mateo County
RDJ Farms, Inc., et al. v. Allegheny Energy Supply
Company, LLC, et al.	May 10, 2002	Superior Court of California—San Joaquin County
Century Theatres, Inc., et al. v. Allegheny Energy
Supply Company, LLC, et al.	May 14, 2002	Superior Court of California—San Francisco County
El Super Burrito, Inc., et al. v. Allegheny Energy
Supply Company, LLC, et al.	May 15, 2002	Superior Court of California—San Mateo County
Leo’s Day and Night Pharmacy, et al. v. Duke
Energy Trading and Marketing, LLC, et al.	May 21, 2002	Superior Court of California—Alameda County
J&M Karsant Family Limited Partnership, et al. v.
Duke Energy Trading and Marketing, LLC, et al.	May 21, 2002	Superior Court of California—Alameda County
Bronco Don Holdings, LLP, et al. v. Duke Energy
Trading and Marketing, LLC, et al.	May 24, 2002	Superior Court of California—San Francisco County
Kurtz v. Duke Energy Trading et al.	October 18, 2002	Superior Court of California—Los Angeles County

These suits were initially filed in California state courts by the plaintiffs and removed to United States district courts. These eight cases were consolidated for purposes of pretrial proceedings with the Six Coordinated Suits described above. These actions are stayed with respect to the Mirant defendants by the filing of the Chapter 11 proceedings of those entities, but are proceeding with respect to the other defendants. On August 28, 2003, the district court granted the motions to dismiss filed by the defendants in the Pastorino, RDJ Farms, Century Theatres, El Super Burrito, Leo’s Day and Night Pharmacy, J&M Karsant and Bronco Don Holdings suits, finding that the plaintiffs’ claims were barred by the filed rate

doctrine and federal preemption. The plaintiffs have appealed that dismissal to the Ninth Circuit. The plaintiff in the Kurtz suit voluntarily dismissed his case without prejudice on February 18, 2004. None of the plaintiffs in these eight cases have filed proofs of claim in the bankruptcy proceedings.

On July 15, 2002, an additional rate payer lawsuit, Public Utility District No. 1 of Snohomish Co. v. Dynegy Power Marketing, et al., was filed in the United States District Court for the Central District of California against various owners of electric generation facilities in California, including Mirant, by Public Utility District No. 1 of Snohomish County, which is a municipal corporation in the state of Washington that provides electric and water utility service. The plaintiff public utility district alleges that defendants violated California’s antitrust statute by conspiring to raise wholesale power prices, injuring plaintiff through higher power purchase costs. The plaintiff also alleges that defendants acted both unfairly and unlawfully in violation of California’s Unfair Competition Act through various unlawful and anticompetitive acts, including the purportedly wrongful acquisition of plants, engagement in “Enron-style” trading and withholding power from the market. The plaintiff seeks restitution, disgorgement of profits, injunctive relief, treble damages and attorney’s fees. The Snohomish suit was consolidated for purposes of pretrial proceedings with the other rate payer suits pending before the United States District Court for the Southern District of California. On January 6, 2003, the district court granted a motion to dismiss filed by the defendants. On September 10, 2004, the United States Court of Appeals for the Ninth Circuit upheld the dismissal of the suit by the district court. The court of appeals ruled that the plaintiff’s claims under California’s antitrust statute and Unfair Competition Act are barred by the doctrine of preemption and the filed rate doctrine, concluding that if prices in the California wholesale electricity markets were not just and reasonable or if the defendants sold electricity in violation of the applicable tariffs, the plaintiff’s only option was to seek a remedy before the FERC under the Federal Power Act. On November 5, 2004, the plaintiff filed a petition for writ of certiorari with the United States Supreme Court seeking to appeal the Ninth Circuit’s decision. The plaintiff in the Snohomish suit has not filed a claim in the bankruptcy proceedings.

On November 20, 2002, a class action suit, Bustamante v. The McGraw-Hill Companies, Inc., et al., was filed in the Superior Court for the County of Los Angeles against certain publishers of index prices for natural gas, gas distribution or marketing companies, owners of electric generation facilities in California and energy marketers, including Mirant, Mirant Americas Energy Marketing and subsidiaries of Mirant Americas Generation. The plaintiff in the Bustamante suit alleged that the defendants violated California Penal Code sections 182 and 395 and California’s Unfair Competition Act by reporting false information about natural gas transactions to the defendants that published index prices for natural gas causing the prices paid by Californians for natural gas and for electricity to be artificially inflated. The suit sought, among other things, disgorgement of profits, restitution, and compensatory and punitive damages. On July 8, 2003, the Superior Court for the County of Los Angeles dismissed the suit, finding that the plaintiffs had failed to allege facts sufficient to warrant relief. The court granted the plaintiffs leave to file an amended complaint, and on August 13, 2003, the plaintiff filed an amended complaint asserting claims under California’s Unfair Competition Act and state antitrust statute against gas distribution or marketing companies, owners of electric generation facilities in California and energy marketers, including the Company and various of its subsidiaries. The amended complaint alleged that the defendants engaged in a scheme to report false gas prices and volumes to companies that published index prices for natural gas in order to manipulate the price indices to benefit themselves. This conduct, the plaintiff asserted, violated California Penal Code section 395 and caused the prices paid by Californians for natural gas to be artificially inflated. The suit was brought as a representative action on behalf of all similarly situated persons, the general public and all taxpayers. The suit sought, among other things, disgorgement of profits, restitution, treble damages and injunctive relief. In November 2003, the plaintiff dismissed the Mirant entities identified as defendants in the amended complaint filed in August 2003.

On December 15, 2003, the plaintiff in the Bustamante suit filed proofs of claim in the bankruptcy proceedings on behalf of a putative class (the “Bustamante Claims”) listing the total amount claimed as

$500 million and attaching the original and first amended complaints. On October 18, 2004, the Debtors filed an objection to the Bustamante Claims. On November 19, 2004, the Debtors filed a motion requesting that the Bankruptcy Court strike the portions of the Bustamante Claims that purported to have been filed on behalf of unnamed absent members of a purported class. On January 26, 2005, the Bankruptcy Court entered an order embodying a ruling made orally on December 1, 2004 granting the motion and striking the Bustamante Claims to the extent they sought to recover on account of any claims other than the claim of Bustamante, in his individual capacity. The Mirant Debtors have also filed a motion to disallow the remaining Bustamante Claims.

On April 28, 2003, a purported class action suit, Egger et al. v. Dynegy, Inc. et al., was filed in the Superior Court for the County of San Diego, California, against various owners of electric generation facilities in California and marketers of electricity and natural gas, including Mirant and various of subsidiaries of Mirant Americas Generation, on behalf of all persons who purchased electricity in Oregon, Washington, Utah, Nevada, Idaho, New Mexico, Arizona and Montana from January 1, 1999. The plaintiffs allege that the defendants engaged in unlawful, unfair, and deceptive practices in the California and western wholesale electricity markets, including withholding energy from the market to create artificial shortages, creating artificial congestion over transmission lines, selling electricity bought in California to out of state affiliates to create artificial shortages and then selling the electricity back into the state at higher prices. The plaintiffs contend that the defendants conspired among themselves and with subsidiaries of Enron Corporation to withhold electricity from the Cal PX and CAISO markets and to manipulate the price of electricity sold at wholesale in the California and western markets. The defendants’ unlawful manipulation of the wholesale energy market, the plaintiffs allege, resulted in supply shortages and skyrocketing energy prices in the western United States, which in turn caused drastic rate increases for retail consumers. The plaintiffs assert claims under California’s antitrust statute and its Unfair Competition Act. The plaintiffs contend that the defendants’ alleged wrongful conduct has caused damages in excess of one billion dollars and seek treble damages, injunctive relief, restitution, and an accounting of the wholesale energy transactions entered into by the defendants from 1998. The defendants removed the suit to the United States District Court for the Southern District of California. The plaintiffs filed an amended complaint in October 2003 that did not include any Mirant entities as defendants due to the stay of litigation resulting from the filing of the Mirant Chapter 11 proceedings, but identified them as “relevant actors.”

Five plaintiffs in the Egger suit (the “Proposed Representatives”) filed proofs of claim (the “Egger Claims”) in the bankruptcy proceedings purportedly on behalf of a class of “all persons and businesses residing in Oregon, Washington, Utah, Nevada, Idaho, New Mexico, Arizona and Montana who were purchasers of electrical energy during the period beginning January 1, 1999 to the present.” Claimants alleged that various misconduct by Mirant and several of its subsidiaries caused inflated prices in wholesale power markets. Claimants listed the damage amount of their claims as “TBD/in excess of $100 million.” Claimants attached the first amended complaint to their proofs of claims. On October 18, 2004, the Debtors filed an objection to the Egger Claims. On November 10, 2004, the parties jointly presented to the Bankruptcy Court a scheduling order in which they agreed that the Egger Claims were sufficiently similar to the Oscar Claims so that the Bankruptcy Court’s ruling on Mirant’s motion to strike the Oscar Claims would also be dispositive as to the Egger Claims. Thus, the Egger Claims were disallowed with prejudice to the extent they sought to recover on account of any claims other than those of the Proposed Representatives in their individual capacities. On January 19, 2005, the Bankruptcy Court approved a settlement agreement with the Proposed Representatives pursuant to which each of the Proposed Representatives will be entitled to receive an allowed, general unsecured claim against Mirant Americas Energy Marketing in the amount of $1,000 in full and final satisfaction of the Egger Claims.

Montana Attorney General Suit

On June 30, 2003, the Montana Attorney General and Flathead Electric Cooperative, Inc. filed a suit in the First Judicial District of Montana, County of Lewis and Clark, against various owners of generating facilities and marketers of electricity and natural gas in western states, including Mirant, alleging that the defendants had engaged in unlawful and unfair business practices in 2000 and 2001 involving the sale of wholesale electricity and natural gas and had manipulated the markets for wholesale electricity and natural gas. The plaintiffs alleged, among other things, that the defendants fixed prices and restricted supply into the markets operated by the Cal PX and CAISO, gamed the power market, provided false information to trade publications to inflate natural gas price indices published by such publications, and engaged in other manipulative practices, including withholding generation, selling generation at inflated prices, submitting false load schedules in order to increase electricity scarcity, creating fictitious congestion and counterflows, and double-selling the same generation to the CAISO. The plaintiffs contended that the defendants conspired with each other and acted in concert with each other in engaging in the conduct alleged. The plaintiffs asserted claims for violation of Montana’s Unfair Trade Practices and Consumer Protection Act and fraud. They seek treble damages, injunctive relief, and attorneys’ fees. The suit was removed to the United States District Court for the District of Montana on July 23, 2003, and on December 5, 2003 the district court remanded the proceeding to the state court. The Montana Attorney General has not filed any proof of claim in the bankruptcy proceedings.

On February 12, 2004, the Montana Public Service Commission initiated an investigation of the Montana retail electricity market affected by transactions involving the western electricity grid. The purpose of the investigation is to determine whether there is evidence of unlawful manipulation of that market related to the high prices for electricity in the western wholesale markets that occurred in 2000 and 2001. The Commission ordered this investigation in response to petitions filed by the Montana Attorney General and Flathead Electric Cooperative, Inc. making allegations similar to those asserted in their suit described above. Mirant and its subsidiaries are not engaged in the generation of electricity or the sale of electricity at retail in Montana and, therefore, do not believe they are subject to the regulatory jurisdiction of the Montana Public Service Commission.

Shareholder-Bondholder Litigation

Mirant Securities Consolidated Action. Twenty lawsuits have been filed since May 29, 2002 against Mirant and four of its officers alleging, among other things, that the defendants violated Sections 10(b) and 20(a) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”) and Rule 10b-5 promulgated thereunder by making material misrepresentations and omissions to the investing public regarding Mirant’s business operations and future prospects during the period from January 19, 2001 through May 6, 2002. The suits have each been filed in the United States District Court for the Northern District of Georgia, with the exception of three suits filed in the United States District Court for the Northern District of California. The three suits filed in California have been transferred by the court to the United States District Court for the Northern District of Georgia and consolidated with the seventeen consolidated suits already pending before that court. The complaints seek unspecified damages, including compensatory damages and the recovery of reasonable attorneys’ fees and costs. The captions of each of the cases follow:

Caption				Date Filed
Kornfeld v. Mirant Corp., et al.				May 29, 2002
Holzer v. Mirant Corp., et al.				May 31, 2002
Abrams v. Mirant Corp., et al.				June 3, 2002
Froelich v. Mirant Corp., et al.				June 4, 2002
Rand v. Mirant Corp., et al.				June 5, 2002
Purowitz v. Mirant Corp., et al.				June 10, 2002
Kellner v. Mirant Corp., et al.				June 14, 2002
Sved v. Mirant Corp., et al.				June 14, 2002
Teaford v. Mirant Corp., et al.				June 14, 2002
Woff v. Mirant Corp., et al.				June 14, 2002
Peruche v. Mirant Corp., et al.				June 14, 2002
Thomas v. Mirant Corp., et al.				June 18, 2002
Urgenson v. Mirant Corp., et al.				June 18, 2002
Orlofsky v. Mirant Corp., et al.				June 24, 2002
Jannett v. Mirant Corp.				June 28, 2002
Green v. Mirant Corp., et al.				July 9, 2002
Greenberg v. Mirant Corp., et al.				July 16, 2002
Law v. Mirant Corp., et al.				July 17, 2002
Russo v. Mirant Corp., et al.				July 18, 2002
Delgado v. Mirant Corp., et al.				October 4, 2002

In November 2002, the plaintiffs in the consolidated suits in the United States District Court for the Northern District of Georgia filed an amended complaint that added additional defendants and claims. The plaintiffs added as defendants Southern Company (“Southern”), the directors of Mirant immediately prior to its initial public offering of stock, and various firms that were underwriters for the initial public offering by the Company. In addition to the claims set out in the original complaint, the amended complaint asserts claims under Sections 11 and 15 of the Securities Act of 1933, alleging that the registration statement and prospectus for the initial public offering of Mirant’s stock misrepresented and omitted material facts. In the amended complaint, the plaintiffs expand their claims under sections 10(b) and 20 of the Securities Exchange Act of 1934 and Rule 10b-5 promulgated thereunder to include statements made to the investing public regarding Mirant’s business operations and future prospects during the period from September 26, 2000 through September 5, 2002. The amended complaint alleges, among other things, that Mirant’s stock price was artificially inflated because the Company failed to disclose in various filings, public statements, and registration statements: (1) that Mirant allegedly reaped illegal profits in California by manipulating energy prices through a variety of alleged improper tactics; (2) that Mirant allegedly failed to take a timely charge to earnings through a write off of its interest in Western Power Distribution; and (3) the accounting errors and internal controls issues that were disclosed in July and November of 2002. On July 14, 2003, the district court dismissed the claims asserted by the plaintiffs based on the Company’s California business activities but allowed the case to proceed on the plaintiffs’ other claims.

This action is stayed as to Mirant by the filing of its Chapter 11 proceeding. On November 19, 2003, the Bankruptcy Court entered an order staying this action also with respect to the other defendants to avoid the suit impeding the ability of Mirant to reorganize or having a negative effect upon Mirant’s assets. The Bankruptcy Court has modified the stay to allow the plaintiffs to proceed with discovery of documentary materials from Mirant and the other defendants. On December 11, 2003, the plaintiffs filed a proof of claim against the estate of Mirant, which was subsequently withdrawn on or about October 10, 2004. Because of the stay applicable to the litigation, Mirant has not yet been released as a defendant in the consolidated lawsuits.

Under a master separation agreement between Mirant and Southern, Southern is entitled to be indemnified by Mirant for any losses arising out of any acts or omissions by Mirant and its subsidiaries in the conduct of the business of Mirant and its subsidiaries. The underwriting agreements between Mirant and the various firms added as defendants that were underwriters for the initial public offering by the Company also provide for Mirant to indemnify such firms against any losses arising out of any acts or omissions by Mirant and its subsidiaries.

Mirant Americas Generation Bondholder Suit. On June 10, 2003, certain holders of senior notes of Mirant Americas Generation maturing after 2006 filed a complaint in the Court of Chancery of the State of Delaware, California Public Employees’ Retirement System, et al. v. Mirant Corporation, et al., that named as defendants Mirant, Mirant Americas Inc., Mirant Americas Generation, certain past and present Mirant directors, and certain past and present Mirant Americas Generation managers. Among other claims, the plaintiffs assert that a restructuring plan pursued by the Company prior to its filing a petition for reorganization under Chapter 11 was in breach of fiduciary duties allegedly owed to them by Mirant, Mirant Americas Inc., and Mirant Americas Generation managers. In addition, the plaintiffs challenge certain dividends and distributions made by Mirant Americas Generation. The plaintiffs seek damages in excess of one billion dollars. Mirant has removed this suit to the United States District Court for the District of Delaware. This action is stayed with respect to the Mirant entities that are defendants by the filing of the Chapter 11 cases. On November 19, 2003, the Bankruptcy Court entered an order staying this action also with respect to the individual defendants to avoid the suit impeding the ability of the Mirant Debtors to reorganize or having a negative effect upon the assets of the Mirant Debtors. The Mirant Americas Generation Creditor Committee filed a motion in Mirant’s bankruptcy proceedings seeking to pursue claims against Mirant, Mirant Americas Inc., certain past and present Mirant directors, and certain past and present Mirant Americas Generation managers similar to those asserted in this suit. The Bankruptcy Court ruled that while the Mirant Americas Generation Creditor Committee has standing to assert claims on behalf of the estate of Mirant Americas Generation, no such claims could be filed without the Bankruptcy Court’s approval and no motions seeking such approval could be filed at least through April 2004. No such motion has been filed with the Bankruptcy Court since April 2004, and the Bankruptcy Court has not authorized any such litigation at this time.

On December 15, 2003, Lehman Commercial Paper Inc. (“Lehman”), as agent for various lenders under certain pre-petition credit agreements, filed a claim against Mirant Americas Generation in the bankruptcy proceedings. On December 15, 2003, Wells Fargo Bank, N.A. (“Wells Fargo”) also filed claims in the bankruptcy proceedings as successor indenture trustee for bond indebtedness under a certain indenture against Mirant Americas Generation. In addition to their original claims, on that same date, Lehman and Wells Fargo filed supplemental claims against Mirant Americas Generation, Mirant and a number of other subsidiaries of Mirant (the “Supplemental Claims”) seeking recovery of principal, interest, fees, and costs under the Mirant Americas Generation loan documents and bond documents, respectively. In their Supplemental Claims, Lehman and Wells Fargo essentially seek to preserve for themselves the claims previously sought to be asserted by the Mirant Americas Generation Creditor Committee.

On November 3, 2004, the Mirant Debtors objected to the Supplemental Claims against Mirant Americas Generation and the other Mirant entities on the grounds that: (1) Lehman and Wells Fargo lack standing to pursue the Supplemental Claims, which are derivative claims belonging to each respective Mirant Debtor’s estate; (2) there is no factual basis for any of the “potential” causes of action against Mirant Americas Generation and no basis whatsoever for the claims against any other Mirant entities; and (3) the Supplemental Claims are duplicative and contingent. In addition to the objection, the Mirant Debtors also filed a motion to dismiss the Supplemental Claims on the basis that the Supplemental Claims do not allege any independent harm to Lehman and Wells Fargo and assert nothing more than derivative claims belonging to the Mirant Debtors’ estates that cannot be asserted by Lehman and Wells Fargo.

On January 24, 2005, the Mirant Debtors filed an expedited motion requesting entry of an order specifying procedures to resolve the Supplemental Claims. The Bankruptcy Court held, on February 15, 2005, that (1) the Supplemental Claims will be withdrawn; (2) the withdrawal of the Supplemental Claims, to the extent that they are not property of the estates of or derivative of a Debtor (“Withdrawn Claims”), will be without prejudice, and the Bar Date will not apply to such claims; and (3) the Withdrawn Claims will not be barred until confirmation of a Plan addresses or extinguishes them and Lehman or Wells Fargo can only raise these claims as issues in the confirmation process.

Shareholder Derivative Litigation. Four purported shareholders’ derivative suits have been filed against Mirant, its directors and certain officers of Mirant. These lawsuits allege that the directors breached their fiduciary duties by allowing the Company to engage in alleged unlawful or improper practices in the California energy market during 2000 and 2001. The practices complained of in the purported derivative lawsuits largely mirror those alleged in the shareholder litigation, the rate payer litigation, and the California Attorney General lawsuits described above. One suit also alleges that the defendant officers engaged in insider trading. The complaints seek unspecified damages on behalf of Mirant, including attorneys’ fees, costs and expenses and punitive damages. The captions of each of the cases follow:

Caption				Date Filed
Kester v. Correll, et al.				June 26, 2002
Pettingill v. Fuller, et al.				July 30, 2002
White v. Correll, et al.				August 9, 2002
Cichocki v. Correll, et al.				November 7, 2002

The Kester and White suits were filed in the Superior Court of Fulton County, Georgia, and were consolidated on March 13, 2003 under the name In re Mirant Corporation Derivative Litigation. The consolidated action has been removed by Mirant to the United States District Court for the Northern District of Georgia. The Pettingill suit was filed in the Court of Chancery for New Castle County, Delaware and was removed by Mirant to the United States District Court for the District of Delaware. The Cichocki suit was filed in the United States District Court for the Northern District of Georgia. These actions are stayed as to Mirant by the filing of its Chapter 11 proceeding. On November 19, 2003, the Bankruptcy Court entered an order staying these actions also with respect to the individual defendants to avoid the suit impeding the ability of Mirant to reorganize or having a negative effect upon Mirant’s assets. On December 8, 2003, the court in the Cichocki suit took notice of the Bankruptcy Court’s Order dated November 19, 2003 staying the litigation and administratively closed the action. No proofs of claims were filed in the Chapter 11 proceedings with respect to the shareholder derivative suits.

ERISA Litigation. On April 17, 2003 and June 3, 2003, two purported class action lawsuits alleging violations of the Employee Retirement Income Security Act (“ERISA”) were filed in the United States District Court for the Northern District of Georgia, under the captions James Brown v. Mirant Corporation, et al. and Greg Waller, Sr. v. Mirant Corporation et al. (the “ERISA Litigation”). The ERISA Litigation names as defendants Mirant, certain of its current and former officers and directors, and Southern. The plaintiffs, who seek to represent a putative class of participants and beneficiaries of Mirant’s 401(k) plans (the “Plans”), allege that defendants breached their duties under ERISA by, among other things, (i) concealing information from the Plans’ participants and beneficiaries; (ii) failing to ensure that the Plans’ assets were invested prudently; (iii) failing to monitor the Plans’ fiduciaries; and (iv) failing to engage independent fiduciaries to make judgments about the Plans’ investments. The factual allegations underlying these lawsuits are substantially similar to those described with respect to the shareholder litigation, the rate payer litigation, and the California Attorney General lawsuits described above. The plaintiffs seek unspecified damages, injunctive relief, attorneys’ fees and costs. On September 2, 2003, the district court issued an order consolidating the two suits. On September 23, 2003, the plaintiffs filed an

amended and consolidated complaint. The amended and consolidated complaint asserted similar factual allegations as the previously filed lawsuits and added as defendants T. Rowe Price Trust Company and certain additional current and former officers of Mirant. The consolidated action is stayed as to Mirant by the filing of its Chapter 11 proceeding. On November 19, 2003, the Bankruptcy Court entered an order staying this action also with respect to the other defendants to avoid the suit impeding the ability of Mirant to reorganize or having a negative effect upon Mirant’s assets. By agreement, however, the suit has been allowed to proceed through the filing of, and ruling by the district court upon, motions to dismiss. On January 9, 2004, T. Rowe Price Trust Company answered the amended and consolidated complaint. All other defendants filed motions on that date seeking dismissal of the plaintiffs’ claims for failure to state a claim upon which relief can be granted. On February 19, 2004, the plaintiffs dismissed their claims against Southern without prejudice. On June 14, 2004, the plaintiffs filed a motion seeking to amend their consolidated complaint to add as defendants Mirant Services, LLC and its board of managers.

On August 4, 2004, the United States District Court for the Northern District of Georgia entered an order staying the ERISA Litigation until the Bankruptcy Court lifts the stays resulting from the filing of Mirant’s bankruptcy proceedings and the order entered by the Bankruptcy Court on November 19, 2003 staying the action with respect to the other defendants. In the order issued August 4, 2004, the district court also denied the motions to dismiss filed by various defendants, including Mirant, and the motion filed by the plaintiffs seeking to amend their consolidated complaint to add as defendants Mirant Services and its board of managers. With respect to both motions, the district court granted the party filing the motion leave to refile the motion once the stays have been lifted by the Bankruptcy Court.

In December 2003, attorneys purporting to act on behalf of the plaintiffs in the ERISA Litigation filed proofs of claim against the Mirant Debtors’ estates, totaling approximately $50 million (the “Brown & Waller Claims”). On October 18, 2004, the Mirant Debtors objected to the Brown & Waller Claims. The parties recently announced to the Bankruptcy Court that they have settled the Brown & Waller Claims, subject to Bankruptcy Court approval. Under the proposed settlement agreement, the claimants agreed to limit their recovery against the Mirant Debtors and any related defendants in the ERISA Litigation to the proceeds paid or payable under certain insurance policies issued to Southern Company and Mirant. The Brown & Waller Claims in the bankruptcy proceedings will be amended to be for a zero dollar amount, and the parties agreed that the Brown & Waller claims will not be further amended.

Mirant Americas Generation Securities Class Action. On June 11, 2003, a purported class action lawsuit alleging violations of Sections 11 and 15 of the Securities Act of 1933 was filed in the Superior Court of Fulton County, Georgia, entitled Wisniak v. Mirant Americas Generation, LLC, et al. The lawsuit names as defendants Mirant Americas Generation and certain current and former officers and managers of Mirant Americas Generation. The plaintiff seeks to represent a putative class of all persons who purchased debt securities of Mirant Americas Generation pursuant to or traceable to an exchange offer completed by Mirant Americas Generation in May 2002 in which $750 million of bonds registered under the Securities Act were exchanged for $750 million of previously issued senior notes of Mirant Americas Generation. The plaintiff alleges, among other things, that Mirant Americas Generation ‘s restatement in April 2003 of prior financial statements rendered the registration statement filed for the May 2002 exchange offer materially false. The complaint seeks damages, interest and attorneys’ fees. The defendants have removed the suit to the United States District Court for the Northern District of Georgia. This action is stayed as to Mirant Americas Generation by the filing of its Chapter 11 proceeding. On November 19, 2003, the Bankruptcy Court entered an order staying these actions also with respect to the individual defendants to avoid the suit impeding the ability of Mirant Americas Generation to reorganize or having a negative effect upon its assets. On December 8, 2003, the court took notice of the Bankruptcy Court’s Order dated November 19, 2003 staying the litigation and administratively closed the action. On December 16, 2003, the plaintiff dismissed Mirant Americas Generation as a defendant, without prejudice,

and filed a proof of claim against Mirant Americas Generation in the bankruptcy proceedings asserting the same claims set forth in the lawsuit.

Mirant Americas Generation and the plaintiff have entered into a stipulation of settlement of the Wisniak suit and the claim filed against Mirant Americas Generation that was approved by the Bankruptcy Court on January 19, 2005. Under the terms of the stipulation of settlement, the plaintiff will seek certification of a class by the district court that will receive $2.25 million to be paid by insurers for Mirant Americas Generation, and an allowed, unsecured claim of $2 million against Mirant subordinated to the claims of its other unsecured creditors. Members of the plaintiff class will have the opportunity to opt out of the settlement, and if class members who choose to opt out own in the aggregate more than 1% of the Mirant Americas Generation bonds that are the subject of the suit, then the Mirant defendants have the option to withdraw from the settlement. The stipulation of settlement must also be approved by the district court to become effective.

PEPCO Litigation

In 2000, Mirant purchased certain power generating assets and certain other assets from PEPCO, including certain power purchase agreements (“PPAs”). Under the terms of the Asset Purchase and Sale Agreement (the “APSA”) Mirant and PEPCO entered into a contractual arrangement (the “Back-to-Back Agreement”) with respect to certain PPAs, including PEPCO’s long-term PPAs with Ohio Edison Company (“Ohio Edison”) and Panda-Brandywine L.P. (“Panda”) under which (1) PEPCO agreed to resell to Mirant all “capacity, energy, ancillary services and other benefits” to which it is entitled under those agreements; and (2) Mirant agreed to pay PEPCO each month all amounts due from PEPCO to Panda or Ohio Edison for the immediately preceding month associated with such capacity, energy, ancillary services and other benefits. The Panda and Ohio Edison PPAs run until 2021 and 2005 respectively. Under the Back-to-Back Agreement, Mirant is obligated to purchase power from PEPCO at prices that are significantly higher than existing market prices for power.

Back-to-Back Agreement Litigation. On August 28, 2003, the Mirant Debtors filed a motion in the bankruptcy proceedings to reject the Back-to-Back Agreement (the “Rejection Motion”), along with an adversary proceeding to enjoin PEPCO and the FERC from taking certain actions against the Mirant Debtors (the “Injunction Litigation”). On October 9, 2003, the United States District Court for the Northern District of Texas entered an order that had the effect of transferring to that court from the Bankruptcy Court the motion filed by the Mirant Debtors seeking to reject the Back-to-Back Agreement and the Injunction Litigation. In December 2003, the district court denied the Rejection Motion and, thereafter, dismissed the Injunction Litigation. The district court ruled that the Federal Power Act preempts the Bankruptcy Code and that a bankruptcy court cannot affect a matter within the FERC’s jurisdiction under the Federal Power Act, including the rejection of a wholesale power purchase agreement regulated by the FERC.

The Mirant Debtors appealed the district court’s orders to the United States Court of Appeals for the Fifth Circuit (the “Fifth Circuit”). The Fifth Circuit reversed the district court’s decision, holding that the Bankruptcy Code authorizes a district court (or bankruptcy court) to reject a contract for the sale of electricity that is subject to the FERC’s regulation under the Federal Power Act as part of a bankruptcy proceeding and that the Federal Power Act does not preempt that authority. The Fifth Circuit remanded the proceeding to the district court for further action on that motion. The Fifth Circuit indicated that on remand the district court could consider applying a more rigorous standard than the business judgment standard typically applicable to contract rejection decisions by debtors in bankruptcy, which more rigorous standard would take into account the public interest in the transmission and sale of electricity.

On December 9, 2004, the district court held that the Back-to-Back Agreement was a part of and not severable from, and therefore could not be rejected apart from, the APSA. The district court also noted

that if the Fifth Circuit overturned the district court’s ruling with respect to severability, the Back-to-Back Agreement should be rejected only if Mirant can prove that the Back-to-Back Agreement burdens the bankrupt estates; that, after scrutiny and giving significant weight to the comments of the FERC relative to the effect of rejection on the public interest, the equities balance in favor of rejecting the Back-to-Back Agreement; and that rejection of the Back-to-Back Agreement would further the Chapter 11 goal of permitting the successful rehabilitation of the Mirant Debtors. The Mirant Debtors have appealed the district court’s December 9, 2004, decision to the Fifth Circuit and requested that the Fifth Circuit hear this appeal on an expedited basis. On March 8, 2005, the Fifth Circuit denied Mirant’s request to have the appeal expedited.

On January 21, 2005, the Mirant Debtors filed a motion in the bankruptcy proceedings to reject the APSA, including the Back-to-Back Agreement but not including other agreements entered into between Mirant and its subsidiaries and PEPCO under the terms of the APSA (the “Second Rejection Motion”). On February 10, 2005, PEPCO filed a motion requesting the district court to assert jurisdiction over and rule upon the Second Rejection Motion rather than having the Bankruptcy Court rule on that motion, arguing that the motion required the consideration of laws other than the Bankruptcy Code. On March 1, 2005, the district court ruled that it would withdraw the reference to the Bankruptcy Court of the Mirant Debtors’ January 21, 2005 motion seeking to reject the APSA and would itself hear that motion.

Suspension of PEPCO Back-to-Back Payments. On December 9, 2004, in an effort to halt excessive out-of-market payments under the Back-to-Back Agreement while awaiting resolution of issues related to the potential rejection of the Back-to-Back Agreement (but prior to notice of entry of the district court’s order of December 9, 2004), Mirant filed a notice in the Bankruptcy Court that Mirant was suspending further payments to PEPCO under the Back-to-Back Agreement absent further order of the court (the “Suspension Notice”). On December 10, 2004, in response to the Suspension Notice, PEPCO filed a motion in the district court seeking a temporary restraining order and injunctive relief to require Mirant to perform under the Back-to-Back Agreement (the “Injunctive Relief Motion”). On December 13, 2004, the district court issued an order referring the Injunctive Relief Motion to the Bankruptcy Court. On December 21, 2004, the Bankruptcy Court issued an order denying the temporary restraining order sought by PEPCO.

On December 14, 2004, PEPCO filed the following additional litigation: (i) a motion seeking relief from the automatic stay provision of Bankruptcy Code section 362(a) to permit PEPCO to terminate performance under the APSA (the “Lift Stay Motion”); (ii) a motion to compel the Mirant Debtors to pay, as administrative expenses, payments that had been suspended under the Back-to-Back Agreement (the “Administrative Expense Motion”); and (iii) an adversary proceeding seeking to compel the Mirant Debtors to make payments under the Back-to-Back Agreement (the “PEPCO Lawsuit”). On December 16, 2004, PEPCO filed a motion requesting the district court to withdraw the reference to the Bankruptcy Court with respect to the litigation filed by PEPCO on December 14, 2004, as well as the Injunctive Relief Motion (the “Second Withdrawal Motion”). On January 4, 2005, the district court denied the Second Withdrawal Motion in its entirety. On January 19, 2005, the Bankruptcy Court entered an order embodying a ruling made orally by the Court on January 14, 2005, in which it denied the Lift Stay Motion and the Administrative Expense Motion, but required the Mirant Debtors to pay amounts due under the Back-to-Back Agreement in January 2005 and thereafter until (i) the Mirant Debtors filed a motion to reject the APSA, (ii) the Fifth Circuit issued an order reversing the district court’s order of December 9, 2004 denying the motion to reject the Back-to-Back Agreement, or (iii) the Mirant Debtors were successful in having the obligations under the Back-to-Back Agreement recharacterized as debt obligations. PEPCO filed an appeal of the Bankruptcy Court’s January 19 order. On March 1, 2005, the district court ordered the Mirant Debtors to pay PEPCO all past-due, unpaid obligations under the Back-to-Back Agreement by March 10, 2005, withdrew the reference to the Bankruptcy Court of the Administrative Expense Motion, and dismissed PEPCO’s appeal of the January 19 order denying the

Administrative Expense Motion as moot. The Mirant Debtors on March 4, 2005 filed a motion requesting the district court to reconsider its order of March 1, 2004 or alternatively to stay that order while the Mirant Debtors appeal it to the Fifth Circuit. On March 7, 2005, the district court modified the March 1 order to require PEPCO to file a response to the Mirant Debtors’ motion for reconsideration by March 14 and to delay until March 18, 2005, the date by which the Mirant Debtors are to pay past-due, unpaid obligations under the Back-to-Back Agreement.

Potential Adjustment Related to Panda Power Purchase Agreement. At the time of the acquisition of the Mirant Mid-Atlantic assets from PEPCO, Mirant also entered into an agreement with PEPCO that, as subsequently modified, provided that the price paid by Mirant for its December 2000 acquisition of PEPCO assets would be adjusted if by March 19, 2005 a binding court order has been entered finding that the Back-to-Back Agreement violates PEPCO’s power purchase agreement with Panda (“Panda PPA”) as a prohibited assignment, transfer or delegation of the Panda PPA or because it effects a prohibited delegation or transfer of rights, duties or obligations under the Panda PPA that is not severable from the rest of the Back-to-Back Agreement. If a court order is entered that triggers the purchase price adjustment, the amount of the adjustment is to be negotiated in good faith by the parties or determined by binding arbitration so as to compensate PEPCO for the termination of the benefit of the Back-to-Back Agreement while also holding Mirant economically indifferent from such court order. Panda initiated legal proceedings in 2000 asserting that the Back-to-Back Agreement violated provisions in the Panda PPA prohibiting PEPCO from assigning the Panda PPA or delegating its duties under the Panda PPA to a third party without Panda’s prior written consent. On June 10, 2003, the Maryland Court of Appeals, Maryland’s highest court, ruled that the assignment of certain rights and delegation of certain duties by PEPCO to Mirant did violate the non-assignment provision of the Panda PPA and was unenforceable. The court, however, left open the issues whether the provisions found to violate the Panda PPA could be severed and the rest of the Back-to-Back Agreement enforced and whether Panda’s refusal to consent to the assignment of the Panda PPA by PEPCO to Mirant was unreasonable and violated the Panda PPA. If the June 10, 2003 decision by the Maryland Court of Appeals or a subsequent decision addressing the Back-to-Back Agreement is determined to have triggered the adjustment to the purchase price paid by Mirant to PEPCO, such adjustment would not be expected to have a material adverse effect on our financial position or results of operations.

City of Alexandria Zoning Action

On December 18, 2004, the City Council for the City of Alexandria, Virginia (the “City Council”) adopted certain zoning ordinance amendments recommended by the City Planning Commission that result in the zoning status of Mirant Potomac River, LLC’s (“Mirant Potomac”) generating plant being changed from “noncomplying use” to “nonconforming use subject to abatement.” Under the nonconforming use status, unless Mirant Potomac applies for and is granted a special use permit for the plant during the seven-year abatement period, the operation of the plant must be terminated within a seven-year period, and no alterations that directly prolong the life of the plant will be permitted during the seven-year period. Typically, the City Council grants special use permits with various conditions and stipulations as to the permitted use.

At its December 18, 2004, meeting, the City Council also approved revocation of two special use permits issued in 1989 (the “1989 SUPs”), one applicable to the administrative office space at Mirant Potomac’s plant and the other for the plant’s transportation management plan. Under the terms of the approved action, the revocation of the 1989 SUPs will take effect 120 days after the City Council revocation, provided, however, that if Mirant Potomac files an application for a special use permit for the entire plant operations within such 120-day period, the effective date of the revocation of the 1989 SUPs will be stayed until final decision by the City Council on such applications. The approved action further provides that if such special use permit application is approved by the City Council, revocation of the 1989

SUPs will be dismissed as moot, and if the City Council does not approve the application, the revocation of the 1989 SUPs will become effective and the plant will be considered an illegal use.

On January 18, 2005, Mirant Potomac and Mirant Mid-Atlantic, LLC filed a complaint against the City of Alexandria and the City Council in the Circuit Court for the City of Alexandria. The complaint seeks to overturn the actions taken by the City Council on December 18, 2004 changing the zoning status of Mirant Potomac’s generating plant and approving revocation of the 1989 SUPs, on the grounds that those actions violated federal, state and city laws. The complaint asserts, among other things, that the actions taken by the City Council constituted unlawful spot zoning, were arbitrary and capricious, constituted an unlawful attempt by the City Council to regulate emissions from the plant, and violated Mirant Potomac’s due process rights. Mirant Potomac and Mirant Mid-Atlantic request the court to enjoin the City of Alexandria and the City Council from taking any enforcement action against Mirant Potomac or from requiring it to obtain a special use permit for the continued operation of its generating plant.

Utility Choice Suit

On February 18, 2005, two providers of electricity at retail in Texas, Utility Choice, L.P. and Cirro Group, Inc., filed a suit in the United States District Court for the Southern District of Texas, entitled Utility Choice, L.P., et al. v. TXU Corp., et al., against numerous owners of generating facilities and power marketers in Texas, including Mirant Americas Energy Marketing, Mirant Americas Development, Inc., and two subsidiaries of Mirant Americas Generation owning generating facilities in Texas. The plaintiffs allege that the defendants, including the Mirant defendants, acting individually and in collusion with each other, engaged in various types of unlawful manipulation of the short term and bilateral wholesale power markets in the Electric Reliability Council of Texas region beginning in 2001 and continuing to the period immediately prior to the filing of the suit that caused the plaintiffs to pay significantly higher prices for power they purchased and to incur other significant costs. The types of conduct that the plaintiffs allege were engaged in by the defendants, including the Mirant defendants, include submitting false schedules and bids, “hockey stick” bidding, withholding generation resources from the market and bidding generation resources at artificially high prices, in each case with the intent to create artificially high market prices. The complaint asserts various causes of action, including without limitation claims under the federal and Texas antitrust acts and the federal Racketeer Influenced and Corrupt Organizations (RICO) Act, as well as state law claims for fraud, negligent misrepresentation, and promissory estoppel. The plaintiffs seek lost profits and other compensatory damages of an unspecified amount, treble damages, exemplary damages and attorneys’ fees.

Environmental Proceedings

EPA Information Request. In January 2001, the Environmental Protection Agency (“EPA”) issued a request for information to Mirant concerning the air permitting and air emission control implications under the EPA’s new source review regulations promulgated under the Clean Air Act of past repair and maintenance activities at Mirant Potomac’s plant in Virginia and Mirant Americas Generation’s Chalk Point, Dickerson and Morgantown plants in Maryland. The requested information concerns the period of operations that predates Mirant’s ownership and lease of the plants. Mirant has responded fully to this request. Under the sales agreement with PEPCO for those plants, PEPCO is responsible for fines and penalties arising from any violation associated with historical operations prior to Mirant’s acquisition of the plants. If a violation is determined to have occurred at any of the plants, the Mirant entity owning the plant may be responsible for the cost of purchasing and installing emission control equipment, the cost of which may be material. If such violation is determined to have occurred after Mirant acquired the plants or, if occurring prior to the acquisition, is determined to constitute a continuing violation, the Mirant entity owning the plant at issue would also be subject to fines and penalties by the state or federal government for the period subsequent to its acquisition of the plant, the cost of which may be material.

California Department of Toxic Substances Control Claim. On January 7, 2004, the California Department of Toxic Substances Control filed a proof of claim in the Mirant Debtors’ bankruptcy proceedings based on civil penalties for alleged non-compliance with state hazardous waste laws and regulations requiring proper documentation of financial assurance for the ultimate closure and post-closure costs, and third-party liability coverage, related to the power plant in Pittsburg, California owned by Mirant America Generation’s subsidiary, Mirant Delta. On December 2, 2004, a settlement was reached that allows the California Department of Toxic Substances Control a general unsecured claim of approximately $50,000 against Mirant Delta in the bankruptcy proceedings.

New York Opacity. On October 20, 2004, the New York State Department of Environmental Affairs Region 3 Staff filed a complaint against Mirant Bowline, Mirant Lovett and Mirant New York with the New York Department of Environmental Conservation. The complaint alleges that the generating facilities owned by Mirant Bowline and Mirant Lovett violated Article 19 of New York’s Environmental Conservation Law and regulations promulgated pursuant to that law by violating opacity standards set for smoke emissions on more than one hundred occasions between the second quarter of 2002 and the first quarter of 2004. The complaint seeks a cease and desist order and fines of $1.96 million against the Mirant defendants.

Potomac River Notice of Violation. On September 10, 2003, the Virginia Department of Environmental Quality issued a Notice of Violation (“NOV”) to Mirant Potomac alleging that it violated its Virginia Stationary Source Permit to Operate by emitting nitrogen oxide (“NOx”) in excess of the “cap” established by the permit for the 2003 summer ozone season. Mirant Potomac responded to the NOV, asserting that the cap is unenforceable, that it can comply through the purchase of emissions credits and raising other equitable defenses. Virginia’s civil enforcement statute provides for injunctive relief and penalties. On January 22, 2004, the EPA issued a NOV to Mirant Potomac alleging the same violation of its Virginia Stationary Source Permit to Operate as set out in the NOV issued by the Virginia Department of Environmental Quality.

On September 27, 2004, Mirant Potomac, Mirant Mid-Atlantic, the Virginia Department of Environmental Quality, the Maryland Department of the Environment, the DOJ and the EPA entered into, and filed for approval with the United States District Court for the Eastern District of Virginia, a consent decree that, if approved, will resolve Mirant Potomac’s potential liability for matters addressed in the NOVs previously issued by the Virginia Department of Environmental Quality and the EPA. The consent decree requires Mirant Potomac and Mirant Mid-Atlantic to install pollution control equipment at Mirant Potomac’s Potomac River plant and at the Morgantown plant leased by Mirant Mid-Atlantic in Maryland; to comply with declining system-wide ozone season NOx emissions caps from 2004 through 2010; to comply with system-wide annual NOx emissions caps starting in 2004; to meet seasonal system average emissions rate targets in 2008; and to pay civil penalties and perform supplemental environmental projects in and around the Potomac River plant expected to achieve additional environmental benefits. Except for the installation of the controls planned for the Potomac River units and the installation of selective catalytic reduction (“SCR”) or equivalent technology at Mirant Mid-Atlantic’s Morgantown Units 1 and 2 in 2007 and 2008, the consent decree does not obligate the Mirant entities to install specifically designated technology, but rather simply to reduce emissions sufficiently to meet the various NOx caps. Moreover, as to the required installations of SCRs at Morgantown, Mirant Mid-Atlantic may choose not to install the technology by the applicable deadlines and leave the units off either permanently or until such time as the SCRs are installed. The aggregate amount of the civil penalties to be paid and costs to be incurred by Mirant Potomac for the supplemental environmental projects is $1.5 million. The consent decree is subject to the approval of the district court and the Bankruptcy Court.

New York Lovett CAMF. The New York State Department of Environmental Affairs issued a notice of violation for the improper closure techniques used on the closure of the coal ash management facility at

Mirant Lovett. This issue is being resolved with the State of New York and may require repair work to be undertaken on the cover.

New York Dissolved Oxygen. Mirant New York is working with the New York State Department of Environment Affairs to settle a consent order that would require us to install equipment to enable us to comply with dissolved oxygen level requirements at the New York Hydro facilities.

Other Governmental Proceedings

Department of Justice Inquiries. In 2002, we were contacted by the DOJ regarding our disclosure of accounting issues, energy trading matters and allegations contained in an amended complaint filed in securities litigation pending against us that we improperly destroyed certain electronic records related to its activities in California. We have been asked to provide copies of the same documents requested by the SEC in their investigation described below in “Securities and Exchange Commission Investigation,” and we have been, and intend to continue, cooperating fully. The DOJ has advised us that it does not intend to take further action with respect to the allegations of improper destruction of electronic records.

In November 2002, we received a subpoena from the DOJ, acting through the United States Attorney’s office for the Northern District of California, requesting information about our activities and those of its subsidiaries for the period since January 1, 1998. The subpoena requested information related to the California energy markets and other topics, including the reporting of inaccurate information to the trade press that publish natural gas or electricity spot price data. The subpoena was issued as part of a grand jury investigation. We have continued to receive additional requests for information from the United States Attorney’s office, and we intend to continue to cooperate fully with the United States Attorney’s office in this investigation.

Securities and Exchange Commission Investigation. In August 2002, we received a notice from the Division of Enforcement of the Securities and Exchange Commission (“SEC”) that it was conducting an investigation of us. The Division of Enforcement has asked for information and documents relating to various topics such as accounting issues (including accounting issues we announced on July 30, 2002 and August 14, 2002), energy trading matters (including round trip trades), our accounting for transactions involving special purpose entities, and information related to shareholder litigation. In late June 2003, the Division of Enforcement advised us that its investigation of Mirant had become a formal investigation in February 2003. We intend to continue to cooperate fully with the SEC.

Department of Labor Inquiries. On August 21, 2003, we received a notice from the Department of Labor (the “DOL”) that it was commencing an investigation pursuant to which it was undertaking to review various documents and records relating to our 401(k) Plans. The DOL also has interviewed our personnel regarding those plans. We will continue to cooperate fully with the DOL.

CFTC Inquiry. In 2002, the Commodity Futures Trading Commission (“CFTC”) asked Mirant Americas Energy Marketing for information about certain buy and sell transactions occurring during the period from January 1, 1999 through June 17, 2002. Mirant Americas Energy Marketing provided information regarding such trades to the CFTC, none of which it considers to be wash trades. In March 2003, Mirant Americas Energy Marketing received a subpoena from the CFTC requesting a variety of documents and information related to Mirant Americas Energy Marketing’s trading of electricity and natural gas and its reporting of transactional information to energy industry publications that prepare price indices for electricity and natural gas in the period from January 1, 1999 through the date of the subpoena. In December 2004, Mirant and Mirant Americas Energy Marketing entered into a settlement with the CFTC that resolves the CFTC’s inquiry into whether Mirant Americas Energy Marketing misrepresented natural gas trading information in 2000 and 2001. Pursuant to the settlement, Mirant and Mirant Americas Energy Marketing consented to the entry of an order by the CTFC in which it makes findings, which are neither admitted or denied by Mirant and Mirant Americas Energy Marketing, that (1) from January 2000

through December 2001, certain Mirant Americas Energy Marketing natural gas traders (i) knowingly reported inaccurate price, volume, and/or counterparty information regarding natural gas cash transactions to publishers of natural gas indices; and (ii) inaccurately reported to index publishers transactions observed in the market as Mirant Americas Energy Marketing transactions and (2) from January to October 2000, certain Mirant Americas Energy Marketing west region traders knowingly delivered the false reports in an attempt to manipulate the price of natural gas. Under the settlement, the CFTC received a subordinated allowed, unsecured claim against Mirant Americas Energy Marketing of $12.5 million in the Chapter 11 proceedings.

Item 4. Submission of Matters to a Vote of Security Holders

None.

PART II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

Common Stock

Our common stock is presently being quoted, and has been quoted since July 16, 2003, on the Pink Sheets Electronic Quotation Service (“Pink Sheets”) maintained by Pink Sheets LLC for the National Quotation Bureau, Inc. Certain restrictions in trading are imposed under a Bankruptcy Court order that requires certain direct and indirect holders of claims, preferred securities and common stock to provide at least ten days advance notice of their intent to buy or sell claims against the Mirant Debtors or shares in Mirant Corporation. The ticker symbol MIRKQ has been assigned to our common stock for over-the-counter quotations. As of February 25, 2005, we had 143,308 holders of record. Prior to July 15, 2003, our common stock was listed under, and traded on, the New York Stock Exchange (“NYSE”). As a result of our filing on July 14, 2003 of a voluntary petition for relief under Chapter 11 of the U.S. Bankruptcy Code, on July 15, 2003, our common stock was suspended from trading by the NYSE and, thereafter, delisted by the NYSE. The following table sets forth (1) the high and low sales prices for our common stock as reported on the NYSE for the first and second quarters of 2003, and (2) the quarterly high and low bid quotations for our common stock as reported on the Pink Sheets for the third and fourth quarter of 2003 and all quarters of 2004. These quotations reflect inter-dealer prices, without retail markup, markdown or commissions, and may not necessarily represent actual transactions.

	Market	High		Low
2003
First Quarter	NYSE	$	2.90	$	1.13
Second Quarter	NYSE	$	3.90	$	1.48
Third Quarter	Pink Sheets	$	0.75	$	0.19
Fourth Quarter	Pink Sheets	$	0.63	$	0.26
2004
First Quarter	Pink Sheets	$	0.75	$	0.40
Second Quarter	Pink Sheets	$	0.40	$	0.26
Third Quarter	Pink Sheets	$	0.48	$	0.30
Fourth Quarter	Pink Sheets	$	0.41	$	0.31

Dividends

We will retain any future earnings to fund our operations and meet our cash and liquidity needs. Therefore, we do not anticipate paying any cash dividends on our common stock in the foreseeable future.

Under the proposed Plan, our existing common stock would be cancelled upon our emergence from bankruptcy and our current equity holders would then receive any surplus value after creditors are paid in full and junior interests in the trust formed under the proposed Plan plus the right to a pro rata share of warrants issued by the new company (“New Mirant”) if they vote to accept the proposed Plan (warrants would give each holder the right to purchase New Mirant shares at a set price within a certain period of time). The amount equity holders will receive, if anything, will be determined by the Bankruptcy Court in a valuation hearing to commence in mid-April 2005. Accordingly, we urge that appropriate caution be exercised with respect to existing and future investments in our securities.

The Mirant Trust I trust preferred stock is presently being quoted on the Pink Sheets under the ticker symbol MIRPQ. These trust preferred securities are obligations of the Mirant Trust I and, as such, are not direct obligations of Mirant Corporation. As a result, they are not addressed specifically as part of the proposed Plan. Mirant Trust I holds $356 million in aggregate principal amount of junior unsecured

convertible debentures of Mirant Corporation, the principal and interest on which are pledged to the payment of the trust preferred securities. Mirant Trust I has agreed that these debentures are subordinated to certain “senior indebtedness” of Mirant Corporation, including indebtedness under the respective credit facilities and debt securities of Mirant Corporation. If all senior indebtedness is paid in full, the holders of the subordinated debentures would receive payments up to their aggregate principal amount, if available.

Item 6. Selected Financial Data

The following discussion should be read in conjunction with our consolidated financial statements and the notes thereto, which are included elsewhere in this Form 10-K. The following table presents our selected consolidated financial information, which is derived from our consolidated financial statements. The financial information for the periods prior to our separation from Southern Company on April 2, 2001 does not necessarily reflect what our financial position and results of operations would have been had we operated as a separate, stand-alone entity during those periods.

The following selected financial information should also be read considering that until August 10, 2000, the date of our acquisition of Vastar Resources Inc.’s 40% interest in Mirant Americas Energy Marketing, we accounted for this joint venture under the equity method of accounting. Effective August 10, 2000, Mirant Americas Energy Marketing became a wholly-owned consolidated subsidiary of Mirant.

	Years Ended December 31,
	2004			2003			2002			2001			2000
	(In millions except per share data)
Statement of Operations Data:
Operating revenues	$	4,572		$	5,162		$	4,703		$	7,208		$	3,951
(Loss) income from continuing operations	(410		)	(3,632		)	(2,340		)	465			300
(Loss) income from discontinued operations	(66		)	(174		)	(98		)	(56		)	30
Cumulative effect of changes in accounting principles	—			(29		)	—			—			—
Net (loss) income	(476		)	(3,835		)	(2,438		)	409			330
(Loss) earnings per share:
From continuing operations	$	(1.01	)	$	(8.97	)	$	(5.82	)	$	1.36		$	1.03
From discontinued operations	(0.16		)	(0.43		)	(0.24		)	(0.16		)	0.11
From cumulative effect of changes in accounting principles	—			(0.07		)	—			—			—
Net (loss) income	$	(1.17	)	$	(9.47	)	$	(6.06	)	$	1.20		$	1.14

	As of December 31,
	2004			2003			2002		2001		2000
Balance Sheet Data:
Total assets	$	11,424		$	12,333		$	19,423	$	22,043	$	24,136
Total long-term debt	1,375			1,538			8,822		8,435		5,596
Liabilities subject to compromise	9,211			9,077			—		—		—
Subsidiary obligated mandatorily redeemable preferred securities	—			—			—		—		950
Company obligated mandatorily redeemable securities of a subsidiary holding solely parent company debentures	—			—			345		345		345
Stockholders’ (deficit) equity	(1,318		)	(823		)	2,955		5,258		4,164

Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Executive Summary

Overview

We operate as a debtor-in-possession under the jurisdiction of the Bankruptcy Court in accordance with Chapter 11 of the Bankruptcy Code. As a result, our financial statements include the results of Bankruptcy Court actions, probable claims against our estate and professional and administrative costs related to the bankruptcy process.

In 2004, we allocated a substantial amount of resources to bankruptcy restructuring, which includes resolving claims disputes and contingencies, determining enterprise value and capital structure and negotiating a plan of reorganization with the Statutory Committees. In addition to financial restructuring activities, we are preparing to operate after our emergence from Chapter 11 protection. We currently plan to emerge from Chapter 11 in mid-2005. On January 19, 2005, we filed our proposed Plan with the Bankruptcy Court.

In general, it is our current view that the U.S. electricity markets have excess generation capacity. Additionally, generation capacity is expected to exceed combined demand levels and reserve generation targets through 2008 to 2010 for most major markets. This market situation has the potential to result in continued narrow fuel to electricity conversion spreads. In this environment, customers typically transact over shorter durations and rely more heavily on spot markets to meet their energy needs, thus making it more difficult for us to sell our power for longer-term durations and at prices that provide a reasonable return, most notably on our gas fired units.

For our U.S.-based generation business, changing commodity prices can result in volatile financial results as these forward power contracts and other derivative instruments do not currently receive cash flow hedge accounting treatment in our financial statements. Instead, these contracts are reflected in our financial statements at fair value, resulting in volatility in our gross margin. Our unrealized gains and losses for each period reflect changes in fair value of commodity contracts not yet settled and the reversal of unrealized gains and losses recognized in previous periods that settled in the current reporting period. We plan to implement cash flow hedge accounting during 2005, which will reduce volatility from these transactions in the income statement.

Our power generation businesses and our integrated utilities in the Philippines and Caribbean continue to provide consistent, stable gross margin and operating cash flows. In general, we expect increased demand levels in the countries in which these businesses operate.

For the years ended December 31, 2004, 2003 and 2002, our gross margin included the following (in millions):

	Years Ended December 31,
	2004			2003			2002
Realized gross margin(1)	$	1,460		$	1,678		$	1,663
TPA amortization	344			426			423
Unrealized gains (losses) on PPAs	168			171			35
Net unrealized losses on asset management, optimization and legacy portfolios(1)	(20		)	(297		)	100
Net unrealized gross margin	148			(126		)	135
Total gross margin	$	1,952		$	1,978		$	2,221

(1) Gross margin for the year ended December 31, 2003 reflects $188 million of unrealized losses offset by $188 million of realized gross margin related to energy contracts terminated by counterparties as a result of our Chapter 11 filings. As a result of the terminations, the unrealized gains on these contracts became realized in the third quarter of 2003.

Financial Performance

We reported an operating loss of $18 million for the year ended December 31, 2004 compared to an operating loss of $2,864 in 2003. The $2,846 million change in operating loss is detailed as follows (in millions):

	Favorable/ (Unfavorable)
Gross margin(1)		$	(26	)
Operations and maintenance(2)		81
Depreciation and amortization		32
Goodwill impairment losses(3)		1,485
Long-lived asset impairment losses(4)		1,339
Other impairment losses and restructuring charges		34
(Loss) gain on sales of assets, net(5)		(99		)
Change in operating loss		$	2,846

(1) Gross margin decreased $26 million in 2004 compared to 2003 primarily due to lower transition power agreement amortization and unrealized losses stemming from an increase in electricity prices partially offset by new rates in Jamaica in 2004 and higher realized margins from increased prices in 2004. The lower transition power agreement amortization is due to the revisions to the contracts as part of a late 2003 settlement and expiration of one of the contracts in 2004.

(2) Operations and maintenance expense decreased by $81 million primarily due to cost cutting efforts, lower bad debt expenses, favorable property tax settlements and write back of a receivable stemming from bankruptcy court actions of one of our customers.

(3) Goodwill impairment losses decreased by $1,485 million in 2004 compared to 2003. In 2003 we wrote off all goodwill related to our North America business of $2,067 million due to lower cash flow prospects of the business. In 2004, we wrote off the remaining goodwill amounts related to our Asia business of $582 million. See “Critical Accounting Policies and Estimates” and Note 8 to our consolidated financial statements contained elsewhere in this report.

(4) Long-lived asset impairment losses decreased by $1,339 million in 2004 compared to 2003. This change is due to the $1,339 million impairment charge in 2003 related to lower cash flow prospects for the North America business. This asset impairment also caused depreciation and amortization expense to decrease in 2004 compared to 2003.

(5) In 2004 we completed the sale of our remaining Canadian natural gas transportation contracts and certain natural gas marketing agreements. As part of the sale agreements, we paid approximately $12 million to a third party to assume approximately $28 million of net liabilities. We recognized a gain of approximately $16 million in connection with the sale of these agreements. In 2004 we recorded a loss on sale of assets of approximately $65 million related to the planned sale of three natural gas combustion turbines that is reflected in the loss (gain) on sales of assets, net in the consolidated statements of operations. In 2003, we had a gain on sale of assets of $46 million primarily related to the sale of gas storage contracts in our Canadian trading operations.

Bankruptcy Considerations

Through the bankruptcy process, we intend to restructure the Company and establish a capital structure that is consistent with the effects of overcapacity and resulting lower margins and reduced cash flow in the competitive power generation business. While in bankruptcy, we expect our financial results to continue to be volatile as asset impairments, asset dispositions, restructuring activities, contract

terminations and rejections, and claims assessments will significantly impact our consolidated financial statements. As a result, our historical financial performance is likely not indicative of our financial performance post-bankruptcy.

In addition, upon emergence from Chapter 11, the amounts reported in subsequent consolidated financial statements may materially change relative to historical consolidated financial statements as a result of revisions to our operating plans set forth in the proposed Plan and, if required, the impact of revaluing our assets and liabilities by applying fresh start accounting in accordance with Statement of Position 90-7, “Financial Reporting by Entities in Reorganization under the Bankruptcy Code.”

As part of the bankruptcy process, claims are filed with the Bankruptcy Court related to amounts that claimants believe the Mirant Debtors owe them. These claims, except for claims by certain governmental agencies, were required to be filed with the Court by December 16, 2003 (March 12, 2004 for claims against the Chapter 11 estates of Mirant Americas Energy Capital and Mirant Americas Energy Capital Assets). In the absence of a specific Bankruptcy Court order providing otherwise, all governmental agencies were required to file claims with the Bankruptcy Court by January 12, 2004 (May 17, 2004 for claims against the Chapter 11 estates of Mirant Americas Energy Capital and Mirant Americas Energy Capital Assets). See “Critical Accounting Policies and Estimates” for additional information.

On January 19, 2005, we filed a proposed Plan and Disclosure Statement in the Bankruptcy Court. For further discussion, see Item 1 contained elsewhere in this report.

Business Review and Market Environment

North America

Given our current view of the market, certain of our U.S. generating assets will need to overcome several hurdles to remain operational. The following is a summary of our key strategic initiatives.

In the Northeast region, certain power plants that are adversely impacted by overcapacity in the region and significant environmental capital expenditure requirements may be permanently shutdown or mothballed if current conditions persist or we are unsuccessful in reaching an agreement on a regulatory solution. Another significant issue in the Northeast region is our New York property tax disputes at Lovett and Bowline power plants. See Note 15 to our consolidated financial statements for additional information. At our current tax rates, these New York power plants are forecast to have negative operating cash flows. Without substantial tax relief, we will likely sell, permanently shutdown or abandon these plants. In addition, our New York power plants face a challenging operating environment due to poor supply/demand fundamentals.

In the Mid-Atlantic region, our historical financial results include significant non-cash revenue from the amortization of the then-fair values of the TPA liabilities assumed as part of our acquisition of generation assets from PEPCO. This non-cash revenue comprised approximately 29%, 35% and 29% of the gross margin of our North America segment for the years ended December 31, 2004, 2003 and 2002, respectively. One of the TPAs expired in June 2004 and the remaining TPA expired in January 2005. Since the expiration of the TPA, Mirant Americas Energy Marketing has been economically hedging the output of the Mid- Atlantic portfolio, extending into 2006, in the bilateral market and by entering into structured transactions.

In the West region, litigation related to our RMR contract in California represents a significant contingency that could result in sale or other disposition of some or all of our RMR units. On January 19, 2004, we entered into a settlement agreement related to these contracts that is discussed under “California Settlement” in Note 15. The settlement is subject to the approval of the FERC and the Bankruptcy Court.

In the Mid-Continent region, we are working to either extend our current contracts or enter into new contracts after their expiration dates between May 2004 and May 2014 at our generating facilities in Florida and Georgia. We are also working to open new channels to realize value from our plants in Michigan and Indiana through contracts with other utilities.

We currently expect to permanently or temporarily shutdown generating plants with a total capacity of 1,592 MW over the next five years. Additionally, we do not expect to independently complete our four suspended construction projects that consist of 2,188 MW of generating capacity and will either pursue partnerships to complete these projects or to, sell or abandon them. During 2004, we mothballed the Wrightsville generating facility. In February 2005, we entered in an agreement to sell the Wrightsville facility to Arkansas Electric Cooperative Corporation, subject to Bankruptcy Court approval and certain other regulatory and third-party consents and approvals. We expect the sale of the Wrightsville facility to close in 2005.

In response to the current market conditions, we instituted two cost reduction programs, the Corporate Overhead Initiative (“COI”) and the Operations Performance Initiative (“OPI”) that were completed in 2004. These reductions are included in the forecasts contained in the proposed Plan. COI, an initiative undertaken by the Company to find efficiencies and cut costs where reasonable to do so, is intended to result in forecasted Company-wide savings of $35 million in 2005 and $52 million in 2006 and beyond for both the Corporate and North America segments. OPI is an initiative undertaken by the Company to reduce costs and enhance gross margins in the United States and Jamaica. For North America, the forecasts incorporate expected operational improvements of approximately $176 million per year through 2011. For Jamaica, the forecasts assume savings of approximately $2 million in 2005 and approximately $4 million per year from 2006 through 2009.

International

Our international operations include integrated utilities and generating companies with long-term contracts in cooperation with local governments, which provide more stable earnings and cash flow than our North America business. Our core initiatives for our international businesses include the following:

· continue to perform on our NPC contracts in the Philippines;

· manage regulatory, political and customer relationships;

· reduce the system electricity losses at JPS as part of our continuous improvement efforts;

· add additional generation capacity; and

· expand our energy supply business in the Philippines from available, but uncontracted, generation capacity.

Results of Operations

The following discussion of our performance is organized by reportable operating segment, which is consistent with the way we manage our business. Beginning January 1, 2004, we changed our allocation methodology related to our corporate overhead expenses. As a result, substantially all of our corporate operating expenses are allocated to our North America and International segments. The new methodology allocates costs using several methods but is primarily based on gross margin, property, plant and equipment balances and labor costs. Our allocation methodology may be subject to further change during the Chapter 11 process.

North America

Our North America segment consists primarily of electricity generation (approximately 14,000 MW of generating capacity) and energy trading and marketing activities managed as a combined business. The following table summarizes the operations of our North America segment for the years ended December 31, 2004, 2003, and 2002 (in millions):

	Years Ended December 31,
	2004		2003			Increase/ (Decrease)				2003			2002			Increase/ (Decrease)
Operating Revenues:
Generation	$	3,486	$	4,138			$	(652	)	$	4,138		$	3,352			$	786
Net trading revenues	36		(1		)		37			(1		)	341				(342		)
Total operating revenues	3,522		4,137				(615		)	4,137			3,693				444
Cost of fuel, electricity and other products	2,326		2,904				(578		)	2,904			2,254				650
Gross margin	1,196		1,233				(37		)	1,233			1,439				(206		)
Operating Expenses:
Operations and maintenance	730		701				29			701			770				(69		)
Depreciation and amortization	165		200				(35		)	200			149				51
Goodwill impairment losses	—		2,067				(2,067		)	2,067			—				2,067
Long-lived asset impairment losses	—		1,338				(1,338		)	1,338			509				829
Other impairment losses and restructuring charges	9		19				(10		)	19			270				(251		)
Loss (gain)on sales of assets, net	50		(38		)		88			(38		)	(5		)		(33		)
Total operating expenses	954		4,287				(3,333		)	4,287			1,693				2,594
Operating (loss) income	$	242	$	(3,054	)		$	3,296		$	(3,054	)	$	(254	)		$	(2,800	)

The following table summarizes gross margin by region for our North America segment for the years ended December 31, 2004, 2003 and 2002 (in millions):

	Years Ended December 31,
	2004			2003			Increase/ (Decrease)				2003			2002			Increase/ (Decrease)
Mirant Americas Generation:
Northeast	$	242		$	143			$	99		$	143		$	163			$	(20	)
Mid-Atlantic	424			352				72			352			469				(117		)
West	164			183				(19		)	183			334				(151		)
Other North America generation	170			179				(9		)	179			151				28
TPA amortization	344			426				(82		)	426			423				3
Other, including TPA and PPA losses	(148		)	(50		)		(98		)	(50		)	(101		)		51
Total	$	1,196		$	1,233			$	(37	)	$	1,233		$	1,439			$	(206	)

The following table summarizes capacity factor (average percentage of full capacity used over a year) by region for our North America segment for the years ended December 31, 2004 and 2003:

	Years Ended December 31,
	2004			2003			Increase/ (Decrease)
Mirant Americas Generation
Northeast		33	%		31	%		2	%

Delaware	001-16107	58-2056305
(State or other jurisdiction of Incorporation or Organization)	(Commission File Number)	(I.R.S. Employer Identification No.)
1155 Perimeter Center West, Suite 100, Atlanta, Georgia		30338
(Address of Principal Executive Offices)		(Zip Code)
(678) 579-5000		www.mirant.com
(Registrant’s Telephone Number, Including Area Code)		Web Page

		Page
	PART I
Item 1.	Business	5
Item 2.	Properties	27
Item 3.	Legal Proceedings	29
Item 4.	Submission of Matters to a Vote of Security Holders	55
	PART II
Item 5.	Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	56
Item 6.	Selected Financial Data	57
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	58
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	90
Item 8.	Financial Statements and Supplementary Data	93
Item 9.	Changes In and Disagreements with Accountants on Accounting and Financial Disclosure	94
Item 9A.	Controls and Procedures	94
	PART III
Item 10.	Directors and Executive Officers of the Registrant	95
Item 11.	Executive Compensation	99
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	104
Item 13.	Certain Relationships and Related Transactions	105
Item 14.	Principal Accountant Fees and Services	105
	PART IV
Item 15.	Exhibits and Financial Statement Schedules	107