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UNITED STATES SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, DC 20549
FORM 8-K/A
CURRENT REPORT PURSUANT
TO SECTION 13 OR 15(D) OF THE
SECURITIES EXCHANGE ACT OF 1934
Date of report (Date of earliest event reported) September 30, 2005
NRG Energy, Inc.
 
(Exact Name of Registrant as Specified in Its Charter)
Delaware
 
(State or Other Jurisdiction of Incorporation)
 	 	 	
001-15891	 	41-1724239	
 	
(Commission File Number)	 	(IRS Employer Identification No.)	

211 Carnegie Center	 	Princeton, NJ 08540	
 	
(Address of Principal Executive Offices)	 	(Zip Code)	
609-524-4500
 
(Registrant’s Telephone Number, Including Area Code)
 
(Former Name or Former Address, if Changed Since Last Report)
     Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions ( see  General Instruction A.2. below):
     £ Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
     £ Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
     £ Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
     £ Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

 

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SIGNATURES	
EX-99.06: UNAUDITED QUARTERLY FINANCIAL STATEMENTS FOR WEST COAST POWER LLC	

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TABLE OF CONTENTS
Item 8.01 Other Events
Item 9.01 Exhibits
SIGNATURES
EX-23.1: CONSENT OF DELOITTE & TOUCHE LLP
EX-99.01: QUARTERLY REPORT
EX-99.02: AUDITED FINANCIAL STATEMENTS
EX-99.03: AUDITED FINANCIAL STATEMENTS
EX-99.04: PRO FORMA PRESENTATION OF THE STATEMENTS OF OPERATION
EX-99.05: PRO FORMA PRESENTATION OF THE STATEMENT OF OPERATION
EX-99.06: UNAUDITED QUARTERLY FINANCIAL STATEMENTS OF WEST COAST POWER LLC
EX-99.10: PRO FORMA FINANCIAL STATEMENTS
EX-99.11: PRO FORMA FINANCIAL STATEMENTS
EXPLANATORY NOTE
     This Form 8-K/A is being filed to update our previously filed pro forma financial statements to include a proposed transaction with Dynegy, Inc., or Dynegy, for the acquisition, sale and exchange of ownership interest in power facilities jointly owned by NRG Energy, Inc. and Dynegy. We have agreed to acquire Dynegy’s 50% ownership interest in West Coast Power LLC (WCP) for $205 million (the “WCP Acquisition”) and sell Dynegy our 50% ownership interest in Rocky Road Power LLC (Rocky Road) for $45 million cash. After the transaction, we will be the sole owner of WCP’s 1,808 megawatts (MW) of generation in Southern California. Rocky Road owns a 330 MW gas-fueled power plant located in East Dundee, Illinois. Each transaction is conditioned upon one another and subject to regulatory approval. We expect to close the transaction in the first quarter of 2006 and effectively fund the net cash payment of $160 million with cash held by WCP.
     Other than updating the original Form 8-K filed on December 21, 2005 to include the pro forma effect of this planned acquisition, this Form 8-K/A does not modify the disclosure contained in the original Form 8-K. See footnote 22 through 26 to the Pro Forma Combined Condensed Balance Sheet as of September 30, 2005, footnotes 10 through 16 to the Pro Forma Combined Statement of Operations for the Nine Months Ended September 30, 2005 and footnotes 9 through 16 to the Pro Forma Combined Statement of Operations for the Year Ended December 31, 2004.
     WCP owns and operates 1,808 MW in Southern California as listed below.
 	 	 	 	 	 	 	 	 	
Plant	 	MW	 	Primary Fuel	 	Status	
El Segundo Power, LLC
(El Segundo)	 	 	670	 	 	Gas	 	Tolling agreement through 12/31/05 and from May 1, 2006 through April 30, 2008	
Cabrillo Power I LLC (Encina)	 	 	965	 	 	Gas	 	Reliability-Must-Run, or RMR, status for Units 1-3 and 5 through 12/31/2006.	
Cabrillo Power II LLC (13
combustion turbines in San
Diego area)	 	 	173	 	 	Gas	 	RMR status through 12/31/2006	
Long Beach Generation LLC
(Long Beach)	 	 	N/A	 	 	N/A	 	Retired	
 	 	 	 	 	 	 	 	 	
Total	 	 	1,808	 	 	 	 	 	
Item 8.01 Other Events
     NRG Energy, Inc., or NRG, has filed a registration statement on Form S-3 to register unsecured debt securities, preferred stock and common stock, and non-registered senior debt securities, the issuance of which are together referred to as the Financing Transactions. The Financing Transactions will be entered into to finance the Acquisition (described below) and re-capitalize the Company. In connection with this registration statement, NRG is filing the unaudited pro forma analyses as set forth below.
     On September 30, 2005, NRG entered into an Acquisition Agreement (the “Acquisition Agreement”) with Texas Genco LLC, a Delaware limited liability company (“Texas Genco”), and each of the direct and indirect owners of Texas Genco (the “Sellers”). Pursuant to the Acquisition Agreement, upon the terms and subject to the conditions set forth therein, the Company agreed to purchase all of the outstanding equity interests in Texas Genco (the “Acquisition”). We expect to close this transaction during the first quarter of 2006.
     On a pro forma basis, we estimate that the total purchase price will be $6.121 billion. This amount is comprised of common stock, cash, preferred stock and capitalized expenses. The number of shares to be issued to the Sellers is 35,406,320, of this amount 19,346,788 are from treasury and 16,059,532 are newly issued shares, at a price of $45.37 which is the average NRG share price

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immediately before and after the pro forma date of closing, or September 30, 2005, with a total value of $1.6 billion for the shares. NRG will pay $4.031 billion in cash, issue Cumulative Redeemable Preferred Stock (the “Cumulative Preferred Stock”) at a value of $368 million and will capitalize expenses of $120 million. This purchase price includes the assumption by the Company of approximately $2.74 billion of Texas Genco indebtedness. As a result of the Acquisition, Texas Genco will become a wholly owned subsidiary of the Company.
     Of the pro forma $6.121 billion consideration to the Sellers upon consummation of the Acquisition, the Company is paying $4.031 billion in cash, and must issue a minimum of 35,406,320 shares of the Company’s common stock. At the Company’s election, the remaining consideration with a fair value of $368 million may be comprised of either an additional 9,038,125 shares of common stock, additional cash, shares of a new series of NRG’s Cumulative Preferred Stock or a combination of the foregoing. If issued, the aggregate liquidation preference of the Cumulative Preferred Stock will be equal to the average trading value of 9,038,125 shares of the Company’s common stock over a twenty trading day period prior to closing. If the Company elects to pay all or a portion of the remaining purchase price in cash, the amount payable in cash would be calculated in the same manner. On a pro forma basis we have assumed that the remaining consideration will be paid by issuing the Cumulative Preferred Stock. Thus, our interest expense increased on a pro forma basis for the Cumulative Preferred Stock. Interest expense increased by $41.4 million for the year ended December 31, 2004 and by $33.1 million for the nine months ended September 30, 2005. If we would elect to pay this consideration in cash or common stock, our income from continuing operations before tax would increase by these amounts, respectively.
     If less than $200 million of aggregate liquidation preference of the Cumulative Preferred Stock is issued in the Acquisition, and the Company elects to issue the Cumulative Preferred Stock, then the initial dividend rate on the Cumulative Preferred Stock will be 9%. If more than $200 million of aggregate liquidation preference is issued, then the initial dividend rate on the Cumulative Preferred Stock will be 10%. In either case, the applicable dividend rate will increase by 1% per quarter to a maximum of 2% above the initial dividend rate. The Cumulative Preferred Stock will be redeemable at the option of the Company at any time for cash and will be mandatorily redeemable by the Company on the earlier of seven and one-half years from issuance and a change of control of the Company. On a pro forma basis we have calculated the dividend rate assuming the initial dividend rate is 10%, increasing to 12% after two quarters.
     NRG expects to finance the cash requirements of the Acquisition through a combination of a new senior secured credit facility, an unsecured high yield notes offering and the sale of common and preferred equity securities in the public markets. We have received a commitment letter from Morgan Stanley Senior Funding, Inc. (“Morgan Stanley”) and Citigroup Global Markets, Inc. (“Citigroup”) to provide us with up to $5.2 billion in senior secured debt financing, including up to $3.2 billion under a senior first priority term loan facility, up to $1 billion under a senior first priority secured revolving credit facility and up to $1 billion under a senior first priority secured synthetic letter of credit facility. The commitment letter further provides for up to $5.1 billion in bridge financing to fund all necessary amounts not provided for under the senior secured debt financing. NRG does not intend to draw down on the bridge financing unless the contemplated high yield debt financing and preferred and common equity financings are for some reason unavailable at the time of the closing. The commitment letter is subject to customary conditions to consummation, including the absence of any event or circumstance that would have a material adverse effect on the business, assets, properties, liabilities, condition (financial or otherwise) or results of operations, taken as a whole, of Texas Genco, or Texas Genco and NRG combined, since June 30, 2005. We have agreed to pay Morgan Stanley and Citigroup $44.6 million in connection with the commitment letter, or the Bridge Loan Commitment Fee, and have agreed to indemnify Morgan Stanley and Citigroup against certain liabilities.
     The Financing Transactions will enable us to refinance our outstanding Second Priority Notes and Credit Facility. This Credit Facility includes a senior secured term loan, a revolving credit facility and funded letter of credit facility. In addition, the new financing will supply the source of funds to acquire Texas Genco and to repay their Term Loan Facility and Senior Notes. The following is a brief summary of the companies’ outstanding debt instruments that we expect to refinance with the new debt structure:
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	 	Old Debt Structure	 	 	 	 	 	 	 	
 	 	As of September 30, 2005	 	 	New Debt	 	 	New Debt	 	
(in millions)	 	NRG	 	 	Texas Genco	 	 	Structure	 	 	Term	 	
Term loan – adjustable interest	 	 	447	 	 	 	1,614	 	 	 	3,200	 	 	7 years	
Second Priority Notes	 	 	1,080	 	 	 	n/a	 	 	 	n/a	 	 	 	n/a	 	
Unsecured senior notes	 	 	n/a	 	 	 	1,125	 	 	 	3,600	 	 	7 years	
Revolving credit facility	 	 	150	 	 	 	325	 	 	 	1,000	 	 	5 years	
Funded letter of credit facility	 	 	350	 	 	 	694	 	 	 	n/a	 	 	 	n/a	 	
Synthetic letter of credit facility	 	 	n/a	 	 	 	n/a	 	 	 	1,000	 	 	5 years	
     On a pro forma basis we have assumed that the fixed interest rate for the new unsecured senior notes will be 7.25%. For the new term loan facility we have assumed that the adjustable annual interest rate will be 6.504% for the year ended December 31, 2004 and 6.622% for the nine months ended September 30, 2005. NRG will pay an annual fee of 0.5% for the new revolving credit facility, and when drawn upon, the adjustable interest rate would be the London Interbank Offering Rate plus 2%. On a pro forma basis, we have assumed an annual fee of 2% to have access to the synthetic letter of credit facility.
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     On December 8, 2005 NRG entered into an Asset Purchase and Sale Agreement to sell all the assets of NRG Audrain Generating LLC, or Audrain, to AmerenUE, a subsidiary of Ameren Corporation. For purposes of these pro forma statements we have reflected the sale of assets of Audrain as a discontinued operation. The purchase price is $115 million, subject to customary purchase price adjustments. The transaction is expected to close during the first half of 2006. The sale is subject to customary approvals, including Federal Energy Regulatory Commission, Missouri Public Utilities Commission, Illinois Commerce Commission, and Hart-Scott-Rodino review. We expect to record a gain of approximately $15 million at closing.
     On May 19, 2005, pursuant to the exercise of a right of first refusal by Texas Genco, subsequent to a third party offer to American Electric Power, or AEP, in early 2004, Texas Genco acquired from AEP an additional 13.2% undivided interest in South Texas Project, or STP. We refer to that acquisition as the “ROFR.” As a result, Texas Genco now owns a 44.0% undivided interest in STP. For pro forma purposes, NRG has accounted for the ROFR as a business acquisition and included the ROFR in our pro forma adjustments to the statements of operation.
     On December 27, 2005, NRG entered into purchase and sale agreements for projects co-owned with Dynegy, Inc. Under the agreements, NRG will acquire Dynegy’s 50% ownership interest in WCP, and become the sole owner of WCP’s 1,808 MW of generation in Southern California .  In addition, NRG is selling to Dynegy its 50% ownership interest in Rocky Road Power LLC, or Rocky Road, a 330 MW gas-fueled, simple cycle peaking plant located in Dundee, Illinois. Both of these transactions are conditioned upon one another and NRG will pay Dynegy a net purchase price of $160 million at closing. NRG will fund the net purchase price with cash held by the WCP partnership. NRG anticipates closing both transactions during the first quarter 2006.
     We have determined that the fair value of our equity investment in Rocky Road is equal to the negotiated price of $45 million. The current carrying value of our investment in Rocky Road is $70.2 million and we therefore expect to record in the fourth quarter of 2005 an other than temporary impairment in our investment. On a pro forma basis the total impairment is in the amount of $25.2 million. As the tax basis of Rocky Road is higher than the consideration received and it is not probable that we can utilize any future benefit from this capital loss, there is no tax expense/(benefit) related to this transaction
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Transactional Pro Forma Analysis:
     The following tables present historical condensed consolidated financial information of (i) NRG for the year ended December 31, 2004 and as of and for the nine months ended September 30, 2005, (ii) Texas Genco for the year ended December 31, 2004 and as of and for the nine months ended September 30, 2005, and (iii) the combined company on a pro forma basis for the year ended December 31, 2004 and as of and for the nine months ended September 30, 2005. The combined company on a pro forma basis is shown after giving effect to (a) the reclassification of Audrain as a discontinued operation; (b) the inclusion of the results pursuant to the ROFR; (c) the refinancing of NRG’s old debt structure; (d) the remaining financing and subsequent Acquisition; and (e) the acquisition of the remaining 50% ownership interest in WCP and sale of our 50% ownership interest in Rocky Road.
     The historical consolidated financial information of NRG for the year ended December 31, 2004 is derived from the historical financial information contained in the audited consolidated financial statements of NRG incorporated by reference in this current report Form 8-K/A. The unaudited historical consolidated financial information as of and for the nine months ended September 30, 2005 (i) have been derived from NRG’s unaudited condensed consolidated financial statements which are incorporated by reference in this current report Form 8-K/A, (ii) have been prepared on a similar basis to that used in the preparation of the audited financial statements, and (iii) in the opinion of NRG’s management, include all adjustments necessary for a fair statement of the results for the unaudited interim period.
     The historical consolidated financial information for Texas Genco as of December 31, 2004 were derived from the audited consolidated financial statements of Texas Genco LLC as of December 31, 2004 and the audited consolidated financial statements of Texas Genco Holdings, Inc. as of December 31, 2004, and are included as Exhibits 99.02 and 99.03 to this current report Form 8-K/A. The historical consolidated financial information for Texas Genco as of and for the nine months ended September 30, 2005 (i) were derived from unaudited financial statements of Texas Genco LLC for the nine months ended September 30, 2005 and the unaudited financial statements of Texas Genco Holdings, Inc. for the period from January 1, 2005 through April 13, 2005 (on April 13, 2005 the remaining business of Texas Genco Holdings, Inc. was acquired by Texas Genco LLC) included as Exhibit 99.01 to this current report Form 8-K/A, (ii) have been prepared on a similar basis to that used in the preparation of the aforementioned audited financial statements and, (iii) in the opinion of Texas Genco’s management, include all adjustments necessary for a fair presentation of the results for the unaudited interim period.
     The historical financial information for WCP for the year ended December 31, 2004 were derived from the audited financial statements of WCP for the year ended December 31, 2004 contained as Exhibit 99.1 in NRG’s Form 10-K filed on March 30, 2005. The unaudited historical consolidated financial information as of and for the nine months ended September 30, 2005 (i) have been derived from WCP’s unaudited condensed consolidated financial statements that are included as exhibit 99.06 to this current report on Form 8-K/A, (ii) have been prepared on a similar basis to that used in the preparation of the audited financial statements, and (iii) in the opinion of WCP’s management, include all adjustments necessary for a fair statement of the results for the unaudited interim period.
     The unaudited pro forma combined income statement data and other financial and operating data for the combined company for the year ended December 31, 2004 and for the nine months ended September 30, 2005 give effect to (a) the reclassification of Audrain as a discontinued operation; (b) the inclusion of the results pursuant to the ROFR; (c) the refinancing of NRG’s old debt structure; (d) the remaining financing and subsequent Acquisition; and (e) the acquisition of the remaining 50% ownership interest in WCP and sale of our 50% ownership interest in Rocky Road, as if the transactions had occurred on January 1, 2004. The unaudited pro forma combined balance sheet data as of September 30, 2005 gives effect to (a) the sale of Audrain as of September 30, 2005; (b) the refinancing of NRG’s old debt structure; (c) the remaining financing and subsequent Acquisition; and (d) the acquisition of the remaining 50% ownership interest in WCP and sale of our 50% ownership interest in Rocky Road, as if the transactions had occurred on September 30, 2005. The combined unaudited pro forma financial data presented below do not purport to represent what the combined company’s results of operations would actually have been had the transactions in fact occurred on the dates specified above or to project the combined company’s results of operations for any future period.
     The historical consolidated financial information and the unaudited pro forma combined financial information set forth below should be read in conjunction with (a) the consolidated financial statements of NRG Energy, Inc., the related notes thereto and Management’s Discussion and Analysis of Financial Condition and Results of Operation included in NRG Energy, Inc.’s annual report on Form 10-K for the year ended December 31, 2004 as amended by the Current Report on Form 8-K filed on December 20, 2005, and quarterly report on Form 10-Q for the nine months ended September 30, 2005; (b) the consolidated financial statements of Texas Genco LLC and Texas Genco Holdings, Inc., the related notes thereto and Management’s Discussion and Analysis of Financial Condition and Results of Operation for the year ended December 31, 2004 and for the nine months ended September 30, 2005 filed and incorporated herein by reference as Exhibits 99.01, 99.02 and 99.03 to this current report on Form 8-K/A; and (c) with the financial statements of West Coast Power LLC and the related notes thereto included in NRG Energy, Inc.’s annual report on Form 10-K as Exhibit 99.1 for the year ended December 31, 2004 and financial statements as of and for the nine months ended September 30, 2005 as found in Exhibit 99.06 to this current report on Form 8-K/A.
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     The Acquisition will be accounted for using the purchase method of accounting and, accordingly, the purchase price will be allocated to the assets acquired and liabilities assumed based on the estimated fair value of such assets and liabilities at the date of acquisition. As it is difficult to estimate a pro forma allocation of purchase price without completed asset appraisals, we have made a preliminary allocation estimate based on the latest available information. For purposes of these pro forma statements we have assumed that the consideration paid in excess of the historical book value of net assets acquired is related to the step-up in fair value of Texas Genco’s emission credit inventory, a step-up in the value of Texas Genco’s fixed assets, and an increase in liabilities for assumed out-of-market contracts. Once the Acquisition is closed, the purchase price and allocation may change significantly from the pro forma amounts included herein based on the results of appraisals, changes in market prices, and other analyses, which the Company is obtaining. The other analyses include actuarial studies of employee benefit plans, income tax effects of the Acquisition, analyses of operations to identify assets for disposition and the evaluation of staffing requirements necessary to meet future business needs. Ultimately, the excess of the purchase price over the fair value of the net tangible and identified intangible assets acquired will be recorded as goodwill.
     The following summarizes the estimated pro forma purchase price and allocation impact of the Acquisition on NRG’s financial statements at September 30, 2005:
 	 	 	 	 	 	 	 	 	
 	 	 	 	 	 	(in millions)	 	
Cash paid to Sellers	 	 	 	 	 	$	4,031	 	
Fair value of 10% Mandatorily Redeemable Preferred Stock issued to Sellers	 	 	 	 	 	 	368	 	
NRG common stock issued to Sellers1	 	 	 	 	 	 	1,606	 	
Fees and transaction costs	 	 	 	 	 	 	 	 	
Fees for early repayment of existing Texas Genco debt	 	 	99	 	 	 	 	 	
Investment banker fees	 	 	17	 	 	 	 	 	
 	 	 	 	 	 	 	 	
Total capitalized acquisition expenses	 	 	 	 	 	 	116	 	
 	 	 	 	 	 	 	 	
Total pro forma Purchase Price	 	 	 	 	 	 	6,121	 	

Purchase price allocation:	 	 	 	 	 	 	 	 	
Net book value of Texas Genco assets and liabilities acquired	 	 	 	 	 	 	773	 	
Write-off of Texas Genco deferred financing fees	 	 	 	 	 	 	(109	)	
Step-up in fixed assets	 	 	 	 	 	 	4,943	 	
Step-up in emission credit inventory	 	 	 	 	 	 	1,309	 	
Increase in out-of-market contracts2	 	 	 	 	 	 	(2,506	)	
Elimination of Texas Genco goodwill	 	 	 	 	 	 	(791	)	
Increase in current deferred tax assets	 	 	 	 	 	 	391	 	
Increase in non-current deferred tax liabilities	 	 	 	 	 	 	(260	)	
NRG goodwill	 	 	 	 	 	 	2,371	 	
 	 	 	 	 	 	 	 	
Total allocated	 	 	 	 	 	$	6,121	 	

 	 	 	
1	 	The Company will issue a minimum of 35,406,320 shares of its common stock. At the Company’s election, the remaining consideration may be comprised of either an additional 9,038,125 shares of common stock, additional cash, shares of a new series of NRG’s Cumulative Preferred Stock or a combination. The value of this remaining consideration will be equal to the average trading value of 9,038,125 shares of the Company’s common stock over a twenty day trading period prior to closing.	
 	 	 	
2	 	Assuming the acquisition had occurred at September 30, 2005, a number of energy and gas sale contracts initiated by Texas Genco were considered to be out-of-the-money and consequently, NRG would have to recognize a liability for these contracts at Acquisition. The fair value of these contracts was assessed based on forecasted energy prices that were calculated as of the pro forma acquisition date. A number of these contracts have already been recorded as a liability by Texas Genco. At Acquisition, we will increase this liability by an additional $2.5 billion to a total fair value of $3.4 billion. The lives of these contracts extend until the end of 2010, however, approximately 91% of the value of these contracts extend until the end of 2008 only. The approximate amortization of these liabilities for the fiscal year of 2006 is $1.3 billion, for the fiscal year of 2007 is $1.1 billion and for the fiscal year of 2008 is $0.7 billion.	
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     The WCP Acquisition is a step acquisition as our original equity investment was initiated in a prior period. The purchase price of each acquisition is determined separately per the consideration given at the date of each transaction. Therefore, the purchase price allocation is determined separately based on the fair value for the percentage of net assets acquired at the date of each transaction. The WCP Acquisition will be accounted for using the purchase method of accounting and, accordingly, the purchase price will be allocated to the percentage of assets acquired and liabilities assumed based on the estimated fair value of such assets and liabilities at the date of the transaction. As it is difficult to estimate a pro forma allocation of purchase price without completed asset appraisals, we have made a preliminary allocation estimate based on the latest available information. For purposes of these pro forma statements we have assumed that the consideration paid below the historical book value of net assets acquired is related to the reduction in fair value of WCP’s fixed assets, with an offsetting increase in fair value in WCP’s land and an increase in the fair value of WCP’s emission credit inventory. Once the WCP Acquisition is closed, the purchase price and allocation may change significantly from the pro forma amounts included herein based on the results of appraisals, changes in market prices and analyses of the income tax effects of the acquisition.
     The following summarizes the estimated pro forma purchase price and allocation impact of the WCP Acquisition on NRG’s financial statements at September 30, 2005:
 	 	 	 	 	
 	 	(in millions)	 	
Cash paid to Dynegy, Inc.	 	$	160	 	
Fair value of NRG’s 50% investment in Rocky Road LLC	 	 	45	 	
 	 	 	 	
Total pro forma Purchase Price of WCP Acquisition	 	 	205	 	

Purchase price allocation:	 	 	 	 	
Net book value of 50% of WCP assets and liabilities acquired	 	 	318	 	
Incremental reduction in value in 50% of WCP’s fixed assets	 	 	(120	)	
Incremental increase in value in 50% of WCP’s land	 	 	24	 	
Incremental increase in 50% of WCP’s emission credit inventory	 	 	19	 	
 	 	 	 	
Total allocation	 	 	241	 	

Excess over cost, or Negative Goodwill	 	$	(36	)	

Negative Goodwill is assigned proportionately to reduce the value of fixed assets	 	 	(13	)	
Negative Goodwill is assigned proportionately to reduce the value of land	 	 	(16	)	
Negative Goodwill is assigned proportionately to reduce the value of emission credit inventory	 	 	(7	)	
 	 	 	 	
Total amount allocated after assignment of Negative Goodwill	 	$	205	 	
 	 	 	 	
     Per our current valuation of WCP’s assets and liabilities, the transaction included an element of an excess over cost, or Negative Goodwill, which has been proportionately allocated to reduce the value of WCP’s acquired assets as noted in the table above. Following the proportionate allocation of Negative Goodwill, the incremental increase/(decrease) in value to the acquired assets is as follows:
 	 	 	 	 	
Final incremental decrease in value in 50% of WCP’s fixed assets	 	 	(133	)	
Final incremental increase in value in 50% of WCP’s land	 	 	8	 	
Final incremental increase in value in 50% of WCP’s emission credit inventory	 	 	12	 	
     We have not associated any deferred taxes to the WCP Acquisition as we believe that the value of the assets and liabilities acquired will be very similar for tax and financial reporting purposes, and any basis differences will only be generated after the closing once timing differences due to depreciation and amortization arise. On a pro forma basis, there are is no basis difference as of September 30, 2005.
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Pro Forma Combined Condensed Balance Sheet as of September 30, 2005
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	 	September 30, 2005 (unaudited)	 	
 	 	Historical	 	 	Pro Forma Adjustments	 	 	 	 	
 	 	NRG Energy	 	 	Texas Genco	 	 	West Coast	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	WCP	 	 	 	 	 	 	Pro Forma NRG	 	
(in thousands)	 	Inc.	 	 	LLC	 	 	Power LLC(26)	 	 	Audrain (1)	 	 	Refinancing	 	 	 	 	 	 	Acquisition	 	 	 	 	 	 	Acquisition (22)	 	 	 	 	 	 	Combined	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Current Assets	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Cash and cash equivalents	 	$	504,336	 	 	$	222,393	 	 	$	176,612	 	 	$	15,000	 	 	$	(269,209	)	 	 	(2	)	 	$	(336,417	)	 	 	(9	)	 	$	(160,000	)	 	 	(23	)	 	$	152,715	 	
Restricted cash	 	 	91,508	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	91,508	 	
Accounts receivable, net	 	 	308,839	 	 	 	212,385	 	 	 	48,372	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	569,596	 	
Current portion of notes receivable	 	 	24,934	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	24,934	 	
Income taxes receivable	 	 	31,237	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	31,237	 	
Inventory	 	 	203,547	 	 	 	113,918	 	 	 	16,618	 	 	 	(1,064	)	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	333,019	 	
Derivative instruments valuation	 	 	451,545	 	 	 	—	 	 	 	88,816	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	540,361	 	
Prepayments and other current assets	 	 	129,289	 	 	 	7,931	 	 	 	26,340	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	163,560	 	
Collateral on deposit in support of energy risk management activities	 	 	631,436	 	 	 	—	 	 	 	10,000	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	641,436	 	
Deferred income taxes	 	 	44,832	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	391,221	 	 	 	(10	)	 	 	—	 	 	 	 	 	 	 	436,053	 	
Current assets held for sale and discontinued operations	 	 	—	 	 	 	23,497	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	23,497	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Total current assets	 	 	2,421,503	 	 	 	580,124	 	 	 	366,758	 	 	 	13,936	 	 	 	(269,209	)	 	 	 	 	 	 	54,804	 	 	 	 	 	 	 	(160,000	)	 	 	 	 	 	 	3,007,916	 	

Property, plant and equipment, net	 	 	3,226,714	 	 	 	3,541,822	 	 	 	380,920	 	 	 	(171,000	)	 	 	—	 	 	 	 	 	 	 	4,942,801	 	 	 	(10	)	 	 	(289,842	)	 	 	(23)(24)	 	 	 	11,631,415	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Other assets	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Goodwill — Texas Genco LLC	 	 	—	 	 	 	790,893	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	(790,893	)	 	 	(10	)	 	 	—	 	 	 	 	 	 	 	—	 	
Goodwill — NRG Energy, Inc.	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	2,371,026	 	 	 	(10	)	 	 	—	 	 	 	 	 	 	 	2,371,026	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Equity investments in affiliates	 	 	651,412	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	(223,066	)	 	 	(24	)	 	 	428,346	 	
Notes receivable, less current portion	 	 	712,020	 	 	 	—	 	 	 	—	 	 	 	(239,930	)	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	472,090	 	
Intangible assets, net	 	 	268,897	 	 	 	769,332	 	 	 	3,844	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	1,309,007	 	 	 	(10	)	 	 	12,354	 	 	 	(23	)	 	 	2,363,434	 	
Derivative instruments, net	 	 	31,973	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	31,973	 	
Funded letter of credit	 	 	350,000	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	(350,000	)	 	 	(3	)	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	
Other non-current assets	 	 	132,848	 	 	 	111,160	 	 	 	—	 	 	 	—	 	 	 	720	 	 	 	(4	)	 	 	(44,795	)	 	 	(11	)	 	 	—	 	 	 	 	 	 	 	199,933	 	
Nuclear decommissioning trust	 	 	—	 	 	 	305,392	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	305,392	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Total other assets	 	 	2,147,150	 	 	 	1,976,777	 	 	 	3,844	 	 	 	(239,930	)	 	 	(349,280	)	 	 	 	 	 	 	2,844,345	 	 	 	 	 	 	 	(210,712	)	 	 	 	 	 	 	6,172,194	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Total assets	 	$	7,795,367	 	 	$	6,098,723	 	 	$	751,522	 	 	$	(396,994	)	 	$	(618,489	)	 	 	 	 	 	$	7,841,950	 	 	 	 	 	 	$	(660,554	)	 	 	 	 	 	$	20,811,525	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
8

Table of Contents
Pro Forma Combined Condensed Balance Sheet as of September 30, 2005 (cont’d)
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	 	September 30, 2005 (unaudited)	 	
 	 	Historical	 	 	Pro Forma Adjustments	 	 	 	 	 	 	 	 	 	
 	 	NRG Energy	 	 	Texas Genco	 	 	West Coast	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	WCP	 	 	 	 	 	 	Pro Forma NRG	 	
(in thousands)	 	Inc.	 	 	LLC	 	 	Power LLC	 	 	Audrain (1)	 	 	Refinancing	 	 	 	 	 	 	Acquisition	 	 	 	 	 	 	Acquisition (22)	 	 	 	 	 	 	Combined	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Liabilities	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Current portion of long-term debt	 	 	176,024	 	 	 	18,045	 	 	 	—	 	 	 	—	 	 	 	(80,000	)	 	 	(5	)	 	 	610,200	 	 	 	(12	)	 	 	—	 	 	 	 	 	 	 	724,269	 	
Accounts payable — trade	 	 	152,968	 	 	 	168,913	 	 	 	17,206	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	339,087	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Derivative instruments valuation	 	 	973,143	 	 	 	145,255	 	 	 	88,643	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	1,207,041	 	
Other bankruptcy settlement	 	 	175,945	 	 	 	—	 	 	 	—	 	 	 	(172,321	)	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	3,624	 	
Accrued expenses and other current liabilities	 	 	389,396	 	 	 	154,763	 	 	 	4,894	 	 	 	—	 	 	 	(84,019	)	 	 	(6	)	 	 	(86,426	)	 	 	(13	)	 	 	—	 	 	 	 	 	 	 	378,608	 	
Out-of market contracts	 	 	—	 	 	 	249,419	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	1,076,150	 	 	 	(10	)	 	 	—	 	 	 	 	 	 	 	1,325,569	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Total current liabilities	 	 	1,867,476	 	 	 	736,395	 	 	 	110,743	 	 	 	(172,321	)	 	 	(164,019	)	 	 	 	 	 	 	1,599,924	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	3,978,198	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Long-term debt and capital leases	 	 	2,866,374	 	 	 	2,724,865	 	 	 	—	 	 	 	(239,930	)	 	 	(364,837	)	 	 	(7	)	 	 	1,923,763	 	 	 	(14	)	 	 	—	 	 	 	 	 	 	 	6,910,235	 	
10% Mandatorily Redeemable Preferred Stock	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	368,123	 	 	 	(15	)	 	 	—	 	 	 	 	 	 	 	368,123	 	
Deferred income taxes	 	 	103,199	 	 	 	181,513	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	259,983	 	 	 	(10	)	 	 	—	 	 	 	 	 	 	 	544,695	 	
Derivative instruments valuation	 	 	198,554	 	 	 	188,023	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	386,577	 	
Nuclear decommissioning reserve	 	 	—	 	 	 	291,829	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	291,829	 	
Nuclear decommissioning trust liability	 	 	—	 	 	 	293,771	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	293,771	 	
Out-of-market contracts	 	 	302,639	 	 	 	689,552	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	1,429,895	 	 	 	(10	)	 	 	—	 	 	 	 	 	 	 	2,422,086	 	
Other non-current liabilities	 	 	190,897	 	 	 	219,663	 	 	 	5,472	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	416,032	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Total liabilities	 	 	5,529,139	 	 	 	5,325,611	 	 	 	116,215	 	 	 	(412,251	)	 	 	(528,856	)	 	 	 	 	 	 	5,581,688	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	15,611,546	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Minority Interest	 	 	869	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	869	 	
3.625% Convertible Preferred Stock	 	 	246,191	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	246,191	 	
Stockholders’ equity 4%	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Convertible Preferred Stock	 	 	406,155	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	406,155	 	
5.5% Convertible Preferred Stock	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	486,250	 	 	 	(16	)	 	 	—	 	 	 	 	 	 	 	486,250	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Members’ equity	 	 	—	 	 	 	1,073,871	 	 	 	635,307	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	(1,073,871	)	 	 	(17	)	 	 	(635,307	)	 	 	(23	), (24)	 	 	—	 	
Common stock	 	 	1,000	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	396	 	 	 	(18	)	 	 	—	 	 	 	 	 	 	 	1,396	 	
Additional paid-in capital	 	 	2,427,322	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	1,912,460	 	 	 	(19	)	 	 	—	 	 	 	 	 	 	 	4,339,782	 	
Retained earnings	 	 	203,973	 	 	 	—	 	 	 	—	 	 	 	15,257	 	 	 	(89,633	)	 	 	(8	)	 	 	(29,261	)	 	 	(20	)	 	 	(25,247	)	 	 	(25	)	 	 	75,089	 	
Less treasury stock, at cost	 	 	(663,529	)	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	663,529	 	 	 	(21	)	 	 	—	 	 	 	 	 	 	 	—	 	
Accumulated other comprehensive loss	 	 	(355,753	)	 	 	(300,759	)	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	300,759	 	 	 	(17	)	 	 	—	 	 	 	 	 	 	 	(355,753	)	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Total Stockholders’ Equity	 	 	2,019,168	 	 	 	773,112	 	 	 	635,307	 	 	 	15,257	 	 	 	(89,633	)	 	 	 	 	 	 	2,260,262	 	 	 	 	 	 	 	(660,554	)	 	 	 	 	 	 	4,952,919	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Total Liabilities and Stockholders’ Equity	 	$	7,795,367	 	 	$	6,098,723	 	 	$	751,522	 	 	$	(396,994	)	 	$	(618,489	)	 	 	 	 	 	$	7,841,950	 	 	 	 	 	 	$	(660,554	)	 	 	 	 	 	$	20,811,525	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
9

Table of Contents
Footnotes to Pro Forma Combined Balance Sheet as of September 30, 2005
(1)	 	On December 8, 2005 NRG Energy, Inc. signed an Asset and Purchase Sale Agreement with AmerenUE to sell all of the assets of Audrain. For purposes of these pro forma statements we have reflected the sale of assets of Audrain as a discontinued operation. The purchase price is $115 million, and the expected gain for the sale of Audrain is approximately $15 million before tax.	
I. Refinancing of NRG’s Long-Term Debt
(2)	 	Reflects the proceeds from new debt issued by NRG for refinancing purposes and the payment to retire NRG existing debt:	

Payment to retire NRG’s existing term loan	 	$	(446,625	)	
Payment to retire NRG’s existing Second Priority Notes	 	 	(1,080,412	)	
Payment to retire NRG’s existing revolver balance	 	 	(80,000	)	
Payment of accrued interest for NRG’s old debt structure	 	 	(25,376	)	
Refinancing portion of proceeds from issuing the new term loan	 	 	446,625	 	
Refinancing portion of proceeds from issuing the new unsecured senior notes	 	 	1,080,412	 	
Payment of a premium fee for the retirement of NRG’s existing debt	 	 	(130,000	)	
Payment of financing fees for the new debt structure	 	 	(33,833	)	
 	 	 	 	
Total	 	$	(269,209	)	

(3)	 	Reflects the retirement of the existing letter of credit facility. We have assumed that the new synthetic letter of credit facility totaling $1 billion will remain off-balance sheet. The existing letter of credit facility required a deposit of $350 million, which will be released upon entering into the new facility.	

(4)	 	Reflects adjustment for the reduction of the old debt structure deferred financing costs, and the increase in deferred financing costs for the new debt structure:	

Write-off of existing NRG deferred financing costs	 	$	(33,113	)	
Addition of new deferred financing costs	 	 	33,833	 	
 	 	 	 	
Total	 	$	720	 	

(5)	 	Movement for current portion of long-term debt for the new and old debt structure:	

Reduction of current portion of NRG’s existing term loan	 	$	(4,500	)	
Reduction of NRG’s existing revolver balance	 	 	(80,000	)	
Increase for current portion of new term loan	 	 	4,500	 	
 	 	 	 	
Total	 	$	(80,000	)	

(6)	 	To record the reduction in accrued expenses for the payment of accrued interest and the current tax effect of the financing expenses:	

Reduction in accrued interest due to payment	 	$	(25,376	)	
Reduction in accrued taxes payable due to the write off of financing costs and incurring premium fees	 	 	(58,643	)	
 	 	 	 	
Total	 	$	(84,019	)	

(7)	 	Movement for non-current portion of long-term debt related to the existing debt and proceeds from new debt issued by NRG:	

Reduction of non-current portion of NRG’s existing term loan	 	$	(442,125	)	
Reduction of non-current portion of NRG’s existing Second Priority Notes	 	 	(1,080,412	)	
Reduction of non-current portion of NRG’s existing funded letter of credit facility	 	 	(350,000	)	
Write-off of premium from NRG’s existing debt	 	 	(14,837	)	
Addition to non-current debt which reflects the refinancing portion of the new term loan	 	 	442,125	 	
Addition to non-current debt which reflects the refinancing portion of the new unsecured senior notes	 	 	1,080,412	 	
 	 	 	 	
Total	 	$	(364,837	)	

(8)	 	Reflects write-offs of deferred financing fees associated with NRG’s existing debt structure, and fees related to the refinancing:	

Write-off of deferred finance costs associated with NRG’s existing debt	 	 	(33,113	)	
Write-off of premium from NRG’s existing debt	 	 	14,837	 	
Payment of a premium fee for the retirement of NRG’s existing debt	 	 	(130,000	)	
Tax effect of the above adjustments	 	 	58,643	 	
 	 	 	 	
Total	 	$	(89,633	)	
 	 	 	 	
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II. Acquisition of Texas Genco
(9)	 	Reflects the proceeds from new debt issued by NRG, issuance of common and preferred stock as a source of funds to acquire Texas Genco, less payments to the Texas Genco shareholders and payments to retire Texas Genco existing debt:	

Payment of accrued interest for Texas Genco’s old debt structure	 	 	(26,437	)	
Payment to retire Texas Genco’s existing term loan	 	 	(1,614,000	)	
Payment to retire Texas Genco’s existing Senior Notes	 	 	(1,125,000	)	
Payment to Sellers	 	 	(4,030,699	)	
Proceeds from issuing the acquisition financing portion of the new term loan	 	 	2,753,375	 	
Proceeds from issuing the acquisition financing portion of the new unsecured senior notes	 	 	2,519,588	 	
Proceeds from issuance of 23,474,178 shares of common stock at $42.60 a share, net of issue costs	 	 	970,000	 	
Proceeds from issuance of 500,000 shares of preferred stock at $1,000 a share, net of issue costs	 	 	486,250	 	
Payment of the Bridge Loan Commitment Fee	 	 	(44,625	)	
Fees for early repayment of existing Texas Genco debt	 	 	(99,000	)	
Investment banker fees	 	 	(16,700	)	
Payment of financing fees for the acquisition financing portion of the new debt structure	 	 	(109,169	)	
 	 	 	 	
Total	 	$	(336,417	)	

(10)	 	The preliminary total consideration for the purchase of Texas Genco is comprised of the following:	

Cost of 19,346,788 NRG common shares issued to Sellers from treasury	 	 	663,529	 	
Value in excess of cost of 19,346,788 NRG common shares issued to Sellers from treasury	 	 	214,235	 	
Par value of 16,059,532 newly issued NRG common shares to Sellers	 	 	161	 	
Value in excess of par value of 16,059,532 newly issued NRG common shares to Sellers	 	 	728,460	 	
 	 	 	 	
Sub-total	 	 	1,606,385	 	
Cash paid to Sellers	 	 	4,030,699	 	
Fair value of 10% Mandatorily Redeemable Preferred Stock issued to Sellers	 	 	368,123	 	
Fees for early repayment of existing Texas Genco debt	 	 	99,000	 	
Investment banker fees	 	 	16,700	 	
 	 	 	 	
Total	 	$	6,120,907	 	

 	 	The preliminary purchase price allocation is as follows:	

Elimination of Members Equity	 	 	1,073,871	 	
Elimination of Accumulated Other Comprehensive Loss	 	 	(300,759	)	
 	 	 	 	
Net book value of Texas Genco assets and liabilities acquired	 	 	773,112	 	
Write-off of Texas Genco deferred financing fees	 	 	(109,339	)	
Step-up in Fixed Assets of Texas Genco	 	 	4,942,801	 	
Step-up in emission credit inventory of Texas Genco	 	 	1,309,007	 	
Incremental assumption of a liability for the fair value of current out-of-market contracts	 	 	(1,076,150	)	
Incremental assumption of a liability for the fair value of non-current out-of-market contracts	 	 	(1,429,895	)	
Goodwill recorded by Texas Genco from prior acquisition	 	 	(790,893	)	
Increase in current deferred tax asset	 	 	391,221	 	
Increase in non-current deferred tax liability	 	 	(259,983	)	
Goodwill	 	 	2,371,026	 	
 	 	 	 	
Total	 	$	6,120,907	 	
 	 	 	 	
     Due to the lack of asset appraisals and a future closing date, it is very difficult to estimate a pro forma allocation of purchase price. However, for purposes of these pro forma statements, we have assumed that the consideration in excess of the net assets acquired is related to a step-up in the value of Texas Genco’s fixed assets, a step-up in the value of Texas Genco’s emission credit inventory and goodwill. Once the Acquisition is closed, the purchase price and allocation may change significantly from the pro forma amounts included herein based on the results of appraisals, changes in market prices, the purchase price and allocation to net assets acquired and liabilities assumed and other analyses, which the Company is obtaining. The other analyses include actuarial studies of employee benefit plans, income tax effects of the Acquisition, analyses of operations to identify assets for disposition and the evaluation of staffing requirements necessary to meet future business needs. Ultimately, the excess of the purchase price over the fair value of the net tangible and identified intangible assets acquired will be recorded as goodwill.
(11)	 	Reflects adjustment for the reduction of Texas Genco’s old debt structure deferred financing costs, and the increase in deferred financing costs for the acquisition financing:	

Write-off of existing Texas Genco deferred financing costs	 	$	(109,339	)	
Write-off of Bridge Loan Commitment Fee	 	 	(44,625	)	
Addition of new deferred financing costs for the acquisition financing	 	 	109,169	 	
 	 	 	 	
Total	 	$	(44,795	)	
 	 	 	 	
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(12)	 	Movement for current portion of long-term debt related to the Texas Genco existing debt and proceeds from the new debt issued by NRG for the acquisition financing:	

Reduction of current portion of Texas Genco’s existing term loan	 	 	(16,300	)	
Addition to current debt which reflects the acquisition financing of the new term loan	 	 	626,500	 	
 	 	 	 	
Total	 	$	610,200	 	

(13)	 	To record the reduction in accrued expenses for the payment of accrued interest and the current tax effect of the acquisition financing expenses and to accrue for an expense related to change of control expenses:	

Reduction in Texas Genco’s accrued interest due to payment	 	$	(26,437	)	
Reduction in accrued expenses due to payment of the Bridge Loan Commitment Fee	 	 	(44,625	)	
Increase in accrued expenses related to change of control clause	 	 	3,781	 	
Reduction in accrued taxes payable	 	 	(19,145	)	
 	 	 	 	
Total	 	$	(86,426	)	

(14)	 	Movement for non-current portion of long-term debt related to the Texas Genco existing debt and proceeds from the new debt issued by NRG for the acquisition financing:	

Reduction of non-current portion of Texas Genco’s existing term loan	 	 	(1,597,700	)	
Reduction of non-current portion of Texas Genco’s existing unsecured senior notes	 	 	(1,125,000	)	
Addition to non-current debt which reflects the acquisition financing of the new term loan	 	 	2,126,875	 	
Addition to non-current debt which reflects the acquisition financing of the new unsecured senior notes	 	 	2,519,588	 	
 	 	 	 	
Total	 	$	1,923,763	 	

(15)	 	Reflects the value of the 10% Mandatorily Redeemable Preferred Shares issued to the Sellers for the purchase of Texas Genco as described in the Agreement. These preferred shares are considered to be a debt instrument as they are repayable at the earliest of (a) seven years and six months from the issue date; or (b) on a date of a change of control.	

(16)	 	Reflects the proceeds net of issuance costs for the issuance of 500,000 shares of 5.5% Mandatorily Convertible Preferred Stock at $1,000 a share.	

(17)	 	Elimination of Texas Genco’s historical members equity and accumulated other comprehensive loss.	

(18)	 	Reflects the par value of 16,059,532 shares of NRG’s common stock issued to Sellers due to the acquisition, and the par value of 23,474,178 shares of NRG common stock issued to the public.	

(19)	 	Reflects excess of fair value of $45.37 a share over par value for 16,059,532 shares of common stock issued to Sellers due to the acquisition, the excess of fair value of $42.60 over par value for the issue of 23,474,178 shares of NRG common stock to the public and the excess of fair value of $45.37 a share over cost for the 19,346,788 shares of NRG common stock issued to Sellers from NRG’s treasury.	

Fair value in excess of par value of newly issued NRG common shares to Sellers	 	$	728,460	 	
Fair value in excess of par value for the issue of NRG common stock to the public	 	 	969,765	 	
Fair value in excess of cost of NRG common shares issued to Sellers from treasury	 	 	214,235	 	
 	 	 	 	
Total	 	$	1,912,460	 	

(20)	 	Reflects write-offs of Bridge Loan Commitment Fee and change of control expenses:	

Write-off of Bridge Loan Commitment Fee	 	 	(44,625	)	
Expenses related to change of control clauses	 	 	(3,781	)	
Tax effect of the above adjustments	 	 	19,145	 	
 	 	 	 	
Total	 	$	(29,261	)	

(21)	 	Reflects the issue of 19,346,788 shares of NRG common stock to Sellers from NRG’s treasury, at cost.	
III. Acquisition of WCP and Sale of Rocky Road:
(22)	 	On December 27, 2005, NRG entered into purchase and sale agreements for projects co-owned with Dynegy. Under the agreements, NRG will acquire Dynegy’s 50% ownership interest in WCP, and become the sole owner of WCP’s 1,808 MW of generation in Southern California. In addition, NRG is selling to Dynegy its 50% ownership interest in Rocky Road, a 330 MW gas-fueled, simple cycle peaking plant located in Dundee, Illinois. Both of these transactions are conditioned upon one another and	
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 	 	NRG will pay Dynegy a net purchase price of $160 million at closing. NRG will fund the net purchase price with cash held by the WCP partnership. NRG anticipates closing both transactions during the first quarter 2006.	
 	 	 	
(23)	 	The total consideration for the WCP Acquisition is comprised of the following:	

Cash paid to Dynegy, Inc.	 	 	160,000	 	
Fair value of our 50% investment in Rocky Road	 	 	45,000	 	
 	 	 	 	
Total pro forma Purchase Price for the WCP Acquisition	 	$	205,000	 	

 	 	The preliminary purchase price allocation is as follows:	

Purchase price allocation:	 	 	 	 	
Net book value of 50% of WCP assets and liabilities acquired	 	 	317,654	 	
Incremental reduction in value in 50% of WCP’s fixed assets	 	 	(120,255	)	
Incremental increase in value in 50% of WCP’s land	 	 	24,576	 	
Incremental increase in value in 50% of WCP’s emission credit inventory	 	 	18,751	 	
 	 	 	 	
Total allocation	 	 	240,726	 	

Excess over cost, or Negative Goodwill	 	$	(35,726	)	

Negative Goodwill is assigned proportionately to reduce the value of fixed assets	 	 	(12,970	)	
Negative Goodwill is assigned proportionately to reduce the value of land	 	 	(16,359	)	
Negative Goodwill is assigned proportionately to reduce the value of emission credit inventory	 	 	(6,397	)	
 	 	 	 	
Total amount allocated after assignment of Negative Goodwill	 	$	205,000	 	
 	 	 	 	
     Per our current valuation of WCP’s assets and liabilities, the transaction included an element of an excess over cost, or Negative Goodwill, which has been proportionately allocated to reduce the value of WCP’s acquired assets as noted in the table above. Following the proportionate allocation of negative goodwill, the incremental increase/(decrease) in value to the acquired assets is as follows:
 	 	 	 	 	
Final incremental decrease in value in 50% of WCP’s fixed assets	 	 	(133,225	)	
Final incremental increase in value in 50% of WCP’s land	 	 	8,217	 	
Final incremental increase in value in 50% of WCP’s emission credit inventory	 	 	12,354	 	
     We have not associated any deferred taxes to the WCP Acquisition as we believe that the value of the assets and liabilities acquired will be equal for tax and financial reporting purposes.
     As it is difficult to estimate a pro forma allocation of purchase price without completed asset appraisals, we have made a preliminary allocation estimate based on the latest available information. For purposes of these pro forma statements we have assumed that the consideration paid below the historical book value of net assets acquired is related to the reduction in the fair value of WCP’s fixed assets, with an offsetting increase in fair value in WCP’s land and an increase in the fair value of WCP’s emission credit inventory. Once the WCP Acquisition is closed, the purchase price and allocation may change significantly from the pro forma amounts included herein based on the results of appraisals, changes in market prices and analyses of the income tax effects of the acquisition.
(24)	 	The reduction in our equity investments reflects the sale of Rocky Road and consolidation of our WCP investment:	

Equity investment in Rocky Road	 	 	70,247	 	
Equity investment in WCP	 	 	152,819	 	
 	 	 	 	
Total	 	 	223,066	 	
 	 	 	 	
The allocation of NRG’s equity investment’s carrying value for 50% of WCP is as follows:

Current carrying value of NRG’s 50% investment in WCP	 	 	152,819	 	

Allocation of current carrying value:	 	 	 	 	
Net book value of 50% of WCP’s assets and liabilities acquired	 	 	317,653	 	
Incremental reduction in value in 50% of WCP’s fixed assets	 	 	(164,834	)	
 	 	 	 	
Total allocation	 	 	152,819	 	
 	 	 	 	
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The total reduction in value of WCP’s fixed assets is as follows:
 	 	 	 	 	
Current WCP Acquisition’s incremental decrease in value WCP’s fixed assets	 	 	(133,225	)	
Current WCP Acquisition’s incremental increase in value of WCP’s land	 	 	8,217	 	
Incremental reduction in value of WCP’s fixed assets as reflected in our 50% equity investment in WCP	 	 	(164,834	)	
 	 	 	 	
Total	 	 	(289,842	)	

(25)	 	We have determined that the fair value of our equity investment in Rocky Road is equal to the negotiated price of $45 million. The current carrying value of our investment in Rocky Road is $70.2 million and we therefore expect to record in the fourth quarter of 2005 an other than temporary impairment in our investment. On a pro forma basis the total impairment is in the amount of $25.2 million. As the tax basis of Rocky Road is higher than the consideration received and it is not probable that we can utilize any future benefit from this capital loss, there is no tax expense/(benefit) related to this transaction.	
(26)	 	Certain items from WCP's balance sheet have been reclassified to match NRG's balance sheet classifications. The amount of $10 million has been moved from “Prepayments and other current assets” to “Collateral on deposit in support of energy risk management activities”. We have also reduced inventory by $3.8 million to reflect the classification of emission credits as an intangible asset. We have also condensed the amount of $16.3 million from “Accounts payable affiliates” with “Accounts Payable”.	
IV. Supplementary information:
Non-recurring charges — we have not included the following non-recurring charges in the Pro forma Statement of Operations for the year ended December 31, 2004:
 	 	 	 	 	
Premium fee for the retirement of NRG’s existing debt	 	$	130,000	 	
Bridge loan commitment fee	 	 	44,625	 	
 	 	 	 	
Total	 	$	174,625	 	
 	 	 	 	
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Pro Forma Combined Statement of Operations for the Nine Months Ended September 30, 2005
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	 	Nine Months Ended September 30, 2005 (unaudited)	 	
 	 	Historical	 	 	 	 	 	 	NRG Energy, Inc	 	 	Pro Forma	 	 	 	 	 	 	Pro Forma Adjustments	 	 	 	 	 	 	 	 	
 	 	NRG Energy,	 	 	 	 	 	 	after Discontinued	 	 	Combined Texas	 	 	Historical	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	WCP	 	 	 	 	 	 	Pro Forma NRG	 	
(in thousands)	 	Inc.	 	 	Audrain (2)	 	 	Operations	 	 	Genco LLC (1)	 	 	WCP	 	 	ROFR (3)	 	 	Refinancing	 	 	 	 	 	 	Acquisition	 	 	 	 	 	 	Acquisition (10)	 	 	 	 	 	 	Combined	 	
Operating Revenues	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Revenues from majority-owned operations	 	$	1,942,828	 	 	$	(4,955	)	 	$	1,937,873	 	 	$	1,999,827	 	 	$	216,127	 	 	$	35,623	 	 	 	—	 	 	 	 	 	 	$	990,740	 	 	 	(6	)	 	$	—	 	 	 	 	 	 	$	5,180,190	 	
Operating Costs and Expenses	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Cost of majority-owned operations	 	 	1,555,737	 	 	 	(4,370	)	 	 	1,551,367	 	 	 	1,306,275	 	 	 	190,461	 	 	 	21,413	 	 	 	—	 	 	 	 	 	 	 	84,000	 	 	 	(7	)	 	 	1,297	 	 	 	(11	)	 	 	3,154,813	 	
Depreciation and amortization	 	 	144,317	 	 	 	—	 	 	 	144,317	 	 	 	146,728	 	 	 	16,726	 	 	 	2,370	 	 	 	—	 	 	 	 	 	 	 	187,500	 	 	 	(8	)	 	 	(37,258	)	 	 	(12	)	 	 	460,383	 	
General, administrative and development	 	 	149,641	 	 	 	(249	)	 	 	149,392	 	 	 	70,032	 	 	 	2,831	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	222,255	 	
Other charges	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Gain on sale of assets	 	 	—	 	 	 	—	 	 	 	—	 	 	 	(28,356	)	 	 	(2	)	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	(28,358	)	
Corporate relocation charges	 	 	5,651	 	 	 	—	 	 	 	5,651	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	5,651	 	
Restructuring and impairment charges	 	 	6,223	 	 	 	—	 	 	 	6,223	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	6,223	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Total operating costs and expenses	 	 	1,861,569	 	 	 	(4,619	)	 	 	1,856,950	 	 	 	1,494,679	 	 	 	210,016	 	 	 	23,783	 	 	 	—	 	 	 	 	 	 	 	271,500	 	 	 	 	 	 	 	(35,961	)	 	 	 	 	 	 	3,820,967	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Operating Income	 	 	81,259	 	 	 	(336	)	 	 	80,923	 	 	 	505,148	 	 	 	6,111	 	 	 	11,840	 	 	 	—	 	 	 	 	 	 	 	719,240	 	 	 	 	 	 	 	35,961	 	 	 	 	 	 	 	1,359,223	 	
Other Income (Expense)	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Minority interest in earnings of consolidated subsidiaries	 	 	(36	)	 	 	—	 	 	 	(36	)	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	(36	)	
Equity in earnings of unconsolidated affiliates	 	 	82,501	 	 	 	—	 	 	 	82,501	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	(22,392	)	 	 	(13	)	 	 	60,109	 	
Gain on sales of equity method investments	 	 	15,894	 	 	 	—	 	 	 	15,894	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	15,894	 	
Other income, net	 	 	43,208	 	 	 	—	 	 	 	43,208	 	 	 	4,274	 	 	 	4,654	 	 	 	662	 	 	 	—	 	 	 	 	 	 	 	(14,535	)	 	(16	)	 	 	 	(3,840	)	 	 	(14	)	 	 	34,423	 	
Refinancing expenses	 	 	(44,036	)	 	 	—	 	 	 	(44,036	)	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	—	 	 	 	 	 	 	 	(44,036	)	
Interest expense	 	 	(150,598	)	 	 	—	 	 	 	(150,598	)	 	 	(141,723	)	 	 	—	 	 	 	—	 	 	 	24,311	 	 	 	(4	)	 	 	(150,727	)	 	 	(9	)	 	 	—	 	 	 	 	 	 	 	(418,737	)	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Total other expense	 	 	(53,067	)	 	 	—	 	 	 	(53,067	)	 	 	(137,449	)	 	 	4,654	 	 	 	662	 	 	 	24,311	 	 	 	 	 	 	 	(165,262	)	 	 	 	 	 	 	(26,232	)	 	 	 	 	 	 	(352,383	)	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Income From Continuing Operations Before Income Taxes	 	 	28,192	 	 	 	(336	)	 	 	27,856	 	 	 	367,699	 	 	 	10,765	 	 	 	12,502	 	 	 	24,311	 	 	 	 	 	 	 	553,978	 	 	 	 	 	 	 	9,729	 	 	 	 	 	 	 	1,006,840	 	
Income Tax Expense	 	 	21,201	 	 	 	—	 	 	 	21,201	 	 	 	24,066	 	 	 	—	 	 	 	4,376	 	 	 	9,615	 	 	 	(5	)	 	 	324,983	 	 	 	(5	)	 	 	8,106	 	 	 	(15	)	 	 	392,347	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Income From Continuing Operations	 	$	6,991	 	 	$	(336	)	 	$	6,655	 	 	$	343,633	 	 	$	10,765	 	 	$	8,126	 	 	$	14,696	 	 	 	 	 	 	$	228,995	 	 	 	 	 	 	$	1,623	 	 	 	 	 	 	$	614,493	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Weighted average number of common shares outstanding
— Basic	 	 	85,860	 	 	 	 	 	 	 	85,860	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	144,740	 	
Basic EPS from continuing operations	 	$	(0.08	)	 	 	 	 	 	$	(0.08	)	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	$	4.01	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Weighted average number of common shares outstanding
— Diluted	 	 	85,860	 	 	 	 	 	 	 	85,860	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	166,392	 	
Diluted EPS from continuing operations	 	$	(0.08	)	 	 	 	 	 	$	(0.08	)	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	$	3.69	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
     Also see Earnings per Share schedule for the nine months ended September 30, 2005.

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Footnotes to Pro Forma Combined Statement of Operations for the Nine Months Ended September 30, 2005
(1)	 	The Pro Forma Combined Texas Genco LLC Statement of Operations for the Nine Months Ended September 30, 2005 can be found in Exhibit 99.10.	

(2)	 	On December 8, 2005 NRG Energy, Inc. signed an Asset and Purchase Sale Agreement with Ameren UE to sell all of the assets of Audrain. For purposes of these pro forma statements we have reflected the sale of assets of Audrain as a discontinued operation.	

(3)	 	Reflects pro forma results of additional 13.2% interest in STP acquired in the ROFR for the period from January 1, 2005 until ROFR acquisition date on May 19, 2005.	

(4)	 	Reflects the reversal of interest expense associated with NRG’s existing debt structure, prior to the acquisition of Texas Genco and the recording of interest expenses associated with the new debt structure:	

Reversal of interest expense associated with NRG’s existing debt structure	 	$	108,782	 	
Interest expense associated with the refinancing of NRG’s debt	 	 	(84,471	)	
 	 	 	 	
Total	 	$	24,311	 	

(5)	 	Reflects the tax effect of both the pro forma adjustments (pro forma effective tax rate of 39.5%) and Texas Genco’s pass-through earnings (pro forma effective tax rate of 34.5% — the difference in tax rates is due to a 0% state corporate income tax rate for Texas Genco in the state of Texas), which will now generate taxable income for the combined entity.	

(6)	 	Reflects the increase in revenue due to the amortization of the out-of-money contracts recorded for the Acquisition of Texas Genco 3 .	

(7)	 	Reflects the reversal of Management Fees of $7.5 million which will not be applicable following the Acquisition and the additional amortization expense for emission credits of $91.5 million based on the amount of credits used during this period by Texas Genco.	

(8)	 	Reflects the increase in depreciation expense due to the step-up in the value of fixed assets at the Acquisition of Texas Genco 3 .	

3	 	Due to the lack of asset appraisals and a future closing date, it is difficult to estimate a pro forma allocation of purchase price. However, for purposes of these pro forma statements we have assumed that the consideration in excess of the net assets acquired is related to a step-up in the value of Texas Genco’s fixed assets, a step-up in the value of Texas Genco’s emission credit inventory and Goodwill. Once the Acquisition is closed, the excess of the estimated purchase price may differ considerably from these assumptions based on the results of appraisals, finalization of the purchase price as a result of closing and other analyses, which the Company is obtaining. The other analyses include actuarial studies of employee benefit plans, income tax effects of the Acquisition, analyses of operations to identify assets for disposition and the evaluation of staffing requirements necessary to meet future business needs. Ultimately, the excess of the purchase price over the fair value of the net tangible and identified intangible assets acquired will be recorded as goodwill.	
 	 	 	
 	 	On a pro forma basis we have made a number of assumptions per our best estimates. We have assumed an average remaining useful life of 25 years of the fixed assets acquired, rendering a significant incremental pro forma increase in depreciation expense. The amortization of the emission credit inventory is based on Texas Genco’s use of credits for the period. The amortization of the assumed liability for Texas Genco’s out-of-market contracts is mimicking the expected amortization for the nine month period which would begin on January 1, 2006. Actual results may differ considerably from these pro forma assumptions.	
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(9)	 	Reflects the reversal of interest expense associated with Texas Genco’s existing debt structure and the recording of interest expenses associated with the acquisition financing:	

Reversal of interest expense associated with Texas Genco existing debt structure	 	 	141,723	 	
Interest expense associated with the acquisition financing	 	 	(292,450	)	
 	 	 	 	
Total	 	$	(150,727	)	

(10)	 	On December 27, 2005, NRG entered into purchase and sale agreements for projects co-owned with Dynegy. Under the agreements, NRG will acquire Dynegy’s 50 percent ownership interest in WCP, and become the sole owner of WCP’s 1,808 MW of generation in Southern California. In addition, NRG is selling to Dynegy its 50 percent ownership interest in Rocky Road, a 330 MW gas-fueled, simple cycle peaking plant located in Dundee, Illinois. Both of these transactions are conditioned upon one another and NRG will pay Dynegy a net purchase price of $160 million at closing. NRG will fund the net purchase price with cash held by the WCP partnership. NRG anticipates closing both transactions during the first quarter 2006.	

(11)	 	Due to the step-up in value of emission credits pursuant to the WCP Acquisition, this amount reflects the additional amortization expense of emission credits of $1.3 million. This additional expense was derived from the actual amount of credits used during this period by WCP.	

(12)	 	Reflects the decrease in depreciation expense due to the reduction in the value of fixed assets at the acquisition of WCP. This reduction in the value of fixed assets is due to the WCP Acquisition as well as the reduction in the value of fixed assets as reflected in NRG’s carrying value of it’s equity investment in WCP. Also see footnote 24 to the pro forma balance sheet as of September 30, 2005 for further discussion. We have assumed an average remaining useful life of 6 years of the fixed assets acquired, rendering a pro forma decrease in depreciation expense. The remaining useful life of 6 years is based on preliminary estimates based on the latest available information. This assumption may change based on the final appraisal of WCP.	

(13)	 	Reflects the reduction in equity earnings in unconsolidated affiliates assuming WCP was a wholly owned subsidiary as of January 1, 2004 and that we no longer owned a 50% interest in Rocky Road. The reduction in equity earnings from these investments is as follows:	

Equity earnings from our 50% investment in WCP	 	$	15,218	 	
Equity earnings from our 50% investment in Rocky Road	 	 	7,174	 	
 	 	 	 	
Total	 	$	22,392	 	
 	 	 	 	
For the nine months ended September 30, 2005, our historical equity earnings from WCP have been higher than 50% of WCP’s reported net income. As described in Note 13 to our annual financial statements as of and for the year ended December 31, 2004 as amended in a current report on Form 8-K filed on December 20, 2005, our investment in WCP reflected an intangible asset with a one year remaining life, consisting of the value of WCP’s CDWR energy sales contract that expired on December 31, 2004 and a reduction in the value of WCP’s fixed assets that was established when we emerged from bankruptcy on December 6, 2003. The effect on equity earnings due to the intangible asset expired on December 31, 2004. However, NRG’s equity earnings were adjusted during the nine months ended September 30, 2004 by decreasing WCP’s depreciation expense by approximately $9 million to reflect the new basis of their fixed assets.
(14)	 	On a pro forma basis we have assumed the payment of cash to Dynegy of $160 million was paid as of January 1, 2004. This adjustment reflects the decrease in interest income due to a reduced cash balance based on an average annual interest rate of 3.2%.	

(15)	 	Reflects the tax effect for both the total pro forma “Income from continuing operations before income tax” for the WCP Acquisition of $9.7 million and WCP’s pass-through earnings of $10.8 million, multiplied by an effective tax rate of 39.5%.	

(16)	 	On a pro forma basis we have assumed that the reduction in cash due to the Refinancing and Acquisition of $269.2 million and $336.4 million, respectively (a total of $605.6 million), was paid as of January 1, 2004. This adjustment reflects the decrease in interest income due to a reduced cash balance based on an average annual interest rate of 3.2%.	
Supplementary information:
Sensitivity analysis for adjustable rate financing — as part of the refinancing, the new term loan will be subject to an adjustable rate of interest. For the nine months ended September 30, 2005, on a pro forma basis, if the interest rate would increase or decrease by 1/8% for the entire period, income from continuing operations would increase or decrease by $1.4 million, respectively.
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Pro Forma Combined Statement of Operations for the Year Ended December 31, 2004
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	 	Year Ended December 31, 2004 (unaudited)	 	
 	 	Historical	 	 	 	 	 	 	NRG, Energy, Inc	 	 	Pro Forma	 	 	 	 	 	 	Pro Forma Adjustments	 	 	 	 	
 	 	NRG Energy,	 	 	 	 	 	 	after Discontinued	 	 	Combined Texas	 	 	Historical	 	 	 	 	 	 	 	 	 	 	 	 	 	 	WCP	 	 	Pro Forma NRG	 	
(in thousands)	 	Inc.	 	 	Audrain (2)	 	 	Operations	 	 	Genco LLC (1)	 	 	WCP	 	 	ROFR (3)	 	 	Refinancing	 	 	Acquisition	 	 	Acquisition(9)	 	 	Combined	 	
Operating Revenues	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Revenues from majority-owned operations	 	$	2,347,882	 	 	$	—	 	 	$	2,347,882	 	 	$	2,333,883	 	 	$	725,626	 	 	$	103,270	 	 	 	—	 	 	 	—	 	 	$	(115,751	)(10)	 	$	5,394,910	 	
Operating Costs and Expenses	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Cost of majority-owned operations	 	 	1,490,228	 	 	 	(1,133	)	 	 	1,489,095	 	 	 	1,394,016	 	 	 	358,823	 	 	 	49,530	 	 	 	—	 	 	 	112,000	(6)	 	 	1,782	(11)	 	 	3,405,246	 	
Depreciation and amortization	 	 	208,036	 	 	 	—	 	 	 	208,036	 	 	 	326,212	 	 	 	39,456	 	 	 	6,223	 	 	 	—	 	 	 	250,000	(7)	 	 	(49,677	)(12)	 	 	780,250	 	
General, administrative and development	 	 	210,185	 	 	 	(495	)	 	 	209,690	 	 	 	93,102	 	 	 	198	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	302,990	 	
Other charges (credits)	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Gain on sale of assets	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	(689	)	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	(689	)	
Corporate relocation charges	 	 	16,167	 	 	 	—	 	 	 	16,167	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	16,167	 	
Reorganization items	 	 	(13,390	)	 	 	—	 	 	 	(13,390	)	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	(13,390	)	
Restructuring and impairment charges	 	 	44,661	 	 	 	—	 	 	 	44,661	 	 	 	—	 	 	 	24,348	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	69,009	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Total operating costs and expenses	 	 	1,955,887	 	 	 	(1,628	)	 	 	1,954,259	 	 	 	1,813,330	 	 	 	422,136	 	 	 	55,753	 	 	 	—	 	 	 	362,000	 	 	 	(47,895	)	 	 	4,559,583	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Operating Income	 	 	391,995	 	 	 	1,628	 	 	 	393,623	 	 	 	520,553	 	 	 	303,490	 	 	 	47,517	 	 	 	—	 	 	 	(362,000	)	 	 	(67,856	)	 	 	835,327	 	
Other Income (Expense)	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Minority interest in earnings of consolidated subsidiaries	 	 	(16	)	 	 	—	 	 	 	(16	)	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	(16	)	
Equity in earnings of unconsolidated affiliates	 	 	159,825	 	 	 	—	 	 	 	159,825	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	(75,799	)(13)	 	 	84,026	 	
Write downs and losses on sales of equity method investments	 	 	(16,270	)	 	 	—	 	 	 	(16,270	)	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	(16,270	)	
Other income, net	 	 	26,688	 	 	 	—	 	 	 	26,688	 	 	 	5,654	 	 	 	2,457	 	 	 	676	 	 	 	—	 	 	 	(9,084	)(16)	 	 	(2,400	)(14)	 	 	23,991	 	
Refinancing expenses	 	 	(71,569	)	 	 	—	 	 	 	(71,569	)	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	(71,569	)	
Interest expense	 	 	(266,145	)	 	 	—	 	 	 	(266,145	)	 	 	(185,914	)	 	 	—	 	 	 	—	 	 	 	64,363	(4)	 	 	(233,954	)(8)	 	 	—	 	 	 	(621,650	)	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Total other expense	 	 	(167,487	)	 	 	—	 	 	 	(167,487	)	 	 	(180,260	)	 	 	2,457	 	 	 	676	 	 	 	64,363	 	 	 	(243,038	)	 	 	(78,199	)	 	 	(601,488	)	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Income From Continuing Operations Before Income Taxes	 	 	224,508	 	 	 	1,628	 	 	 	226,136	 	 	 	340,293	 	 	 	305,947	 	 	 	48,193	 	 	 	64,363	 	 	 	(605,038	)	 	 	(146,055	)	 	 	233,839	 	
Income Tax Expense	 	 	65,364	 	 	 	—	 	 	 	65,364	 	 	 	33,676	 	 	 	—	 	 	 	16,605	 	 	 	25,456	(5)	 	 	(153,261	)(5)	 	 	63,237	(15)	 	 	51,077	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Income From Continuing Operations	 	$	159,144	 	 	$	1,628	 	 	$	160,772	 	 	$	306,617	 	 	$	305,947	 	 	$	31,588	 	 	$	38,907	 	 	$	(451,777	)	 	$	(209,292	)	 	$	182,762	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Weighted average number of common shares outstanding — Basic	 	 	99,616	 	 	 	 	 	 	 	99,616	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	158,496	 	
Basic EPS from Continuing Operations	 	$	1.59	 	 	 	 	 	 	$	1.61	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	$	0.98	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Weighted average number of common shares outstanding — Diluted	 	 	100,371	 	 	 	 	 	 	 	100,371	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	158,908	 	
Diluted EPS from Continuing Operations	 	$	1.59	 	 	 	 	 	 	$	1.60	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	$	0.97	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
     Also see Earnings per Share schedule for the year ended December 31, 2004.
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Footnotes to Pro Forma Combined Statement of Operations for the Year Ended December 31, 2004

(1)	 	The Pro Forma Combined Texas Genco LLC Statement of Operations for the Year Ended December 31, 2004 can be found in Exhibit 99.11.	
 	 	 	
(2)	 	On December 8, 2005 NRG Energy, Inc. signed an Asset and Purchase Sale Agreement with AmerenUE to sell all of the assets of Audrain. For purposes of these pro forma statements we have reflected the sale of assets of Audrain as a discontinued operation.	
 	 	 	
(3)	 	Amounts reflect the pro forma results of the additional 13.2% interest in STP acquired in the ROFR as if the acquisition had occurred on January 1, 2004.	
 	 	 	
(4)	 	Reflects the reversal of interest expense associated with NRG’s existing debt structure, prior to the acquisition of Texas Genco and the recording of interest expenses associated with the new debt structure:	

Reversal of interest expense associated with NRG’s existing debt structure	 	$	181,908	 	
Interest expense associated with the refinancing of NRG’s debt	 	 	(117,545	)	
 	 	 	 	
Total	 	$	64,363	 	

(5)	 	Reflects the tax effect of both the pro forma adjustments (pro forma effective tax rate of 39.5%) and Texas Genco’s pass-through earnings (pro forma effective tax rate of 35.2%) which will now generate taxable income for the combined entity.	
 	 	 	
(6)	 	Reflects the reversal of Management Fees of $10 million which will not be applicable following the Acquisition and the additional amortization expense for emission credits of $122 million based on the amount of credits used during this period by Texas Genco	
 	 	 	
(7)	 	Reflects the increase in depreciation expense due to the step-up in the value of fixed assets at the Acquisition of Texas Genco 4 .	

4	 	Due to the lack of asset appraisals and a future closing date, it is difficult to estimate a pro forma allocation of purchase price. However, for purposes of these pro forma statements we have assumed that the consideration in excess of the net assets acquired is related to a step-up in the value of Texas Genco’s fixed assets, a step-up in the value of Texas Genco’s emission credit inventory and Goodwill. Once the Acquisition is closed, the excess of the estimated purchase price may differ considerably from these assumptions based on the results of appraisals, finalization of the purchase price as a result of closing and other analyses, which the Company is obtaining. The other analyses include actuarial studies of employee benefit plans, income tax effects of the Acquisition, analyses of operations to identify assets for disposition and the evaluation of staffing requirements necessary to meet future business needs. Ultimately, the excess of the purchase price over the fair value of the net tangible and identified intangible assets acquired will be recorded as goodwill.	
 	 	 	
 	 	On a pro forma basis we have made a number of assumptions per our best estimates. We have assumed an average remaining useful life of 25 years of the fixed assets acquired, rendering a significant incremental pro forma increase in depreciation expense. The amortization of the emission credit inventory is based on Texas Genco’s use of credits for the year. We have not included amortization of the out-of-market contracts for the year ended December 31, 2004 as the majority of these contracts were entered in December 2004 or during 2005. Actual results may differ considerably from these pro forma assumptions.	
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(8)	 	Reflects the reversal of interest expenses associated with NRG’s existing debt structure, the reversal of interest expense associated with Texas Genco’s existing debt structure and the recording of interest expenses associated with the new debt structure:	

Reversal of interest expense associated with Texas Genco existing debt structure	 	 	185,914	 	
Interest expense associated with the acquisition financing	 	 	(419,868	)	
 	 	 	 	
Total	 	$	(233,954	)	

(9)	 	On December 27, 2005, NRG entered into purchase and sale agreements for projects co-owned with Dynegy. Under the agreements, NRG will acquire Dynegy’s 50% ownership interest in WCP, and become the sole owner of WCP’s 1,808 MW of generation in Southern California. In addition, NRG is selling to Dynegy its 50% ownership interest in Rocky Road, a 330 MW gas-fueled, simple cycle peaking plant located in Dundee, Illinois. Both of these transactions are conditioned upon one another and NRG will pay Dynegy a net purchase price of $160 million at closing. NRG will fund the net purchase price with cash held by the WCP partnership. NRG anticipates closing both transactions during the first quarter 2006.	
 	 	 	
(10)	 	As described in Note 13 to our financial statements filed on Form 10-K for the year ended December 31, 2004, our investment in WCP reflected an intangible asset with a one year remaining life, consisting of the value of WCP’s CDWR energy sales contract that expired on December 31, 2004. This intangible asset was established when we emerged from bankruptcy on December 6, 2003. Assuming we would have purchased the remaining 50% in WCP as of January 1, 2004 we would have established an intangible asset for the entire CDWR energy sales contract of approximately $115.8 million. This intangible asset should be amortized and would reduce WCP’s revenue until the expiration of the CDWR energy sales contract that will occur on December 31, 2004. On a pro forma basis, the entire intangible asset has been amortized during the year ended December 31, 2004, reducing WCP’s revenue by $115.8 million.	
 	 	 	
(11)	 	Due to the step-up in value of emission credits pursuant to the WCP Acquisition, this amount reflects the additional amortization expense of emission credits of $1.8 million. This additional expense was derived from the actual amount of credits used during this period by WCP.	
 	 	 	
(12)	 	Reflects the decrease in depreciation expense due to the reduction in the value of fixed assets at the acquisition of WCP. This reduction in the value of fixed assets is due to the WCP Acquisition as well as the reduction in the value of fixed assets as reflected in NRG’s carrying value of it’s equity investment in WCP. Also see footnote 24 to the pro forma balance sheet as of September 30, 2005 for further discussion. We have assumed an average remaining useful life of 6 years of the fixed assets acquired, rendering a pro forma decrease in depreciation expense. The remaining useful life of 6 years is based on preliminary estimates based on the latest available information. This assumption may change based on the final appraisal of WCP.	
 	 	 	
(13)	 	Reflects the reduction in equity earnings in unconsolidated affiliates assuming WCP was a wholly owned subsidiary as of January 1, 2004 and that we no longer owned a 50% interest in Rocky Road. The reduction in equity earnings from these investments is as follows:	

Equity earnings from our 50% investment in WCP	 	$	68,895	 	
Equity earnings from our 50% investment in Rocky Road LLC	 	 	6,904	 	
 	 	 	 	
Total	 	$	75,799	 	

 	 	For the year ended December 31, 2004, our historical equity earnings from WCP have been lower than 50% of WCP’s reported net income. As described in Note 13 to our annual financial statements as of and for the year ended December 31, 2004 as amended in a current report on Form 8-K filed on December 20, 2005, our investment in WCP reflected an intangible asset with a one year remaining life, consisting of the value of WCP’s CDWR energy sales contract that expired on December 31, 2004 and a reduction in the value of WCP’s fixed assets that was established when we emerged from bankruptcy on December 6, 2003. NRG’s equity earnings were significantly decreased due to the amortization of this intangible asset in the amount of $115.8 million during the year ended December 31, 2004. This decrease was slightly offset by the reduction of WCP’s depreciation expense in the amount of $31.7 million to reflect the new basis of their fixed assets.	
 	 	 	
(14)	 	On a pro forma basis we have assumed the payment of cash to Dynegy of $160 million was paid as of January 1, 2004. This adjustment reflects the decrease in interest income due to a reduced cash balance based on an average annual interest rate of 1.5%.	
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(15)	 	Reflects the tax effect for both the total pro forma “Loss from continuing operations before income tax” for the WCP Acquisition of $146.1 million and WCP’s pass-through earnings of $305.9 million, multiplied by an effective tax rate of 39.5%.	

(16)	 	On a pro forma basis we have assumed that the reduction in cash due to the Refinancing and Acquisition of $269.2 million and $336.4 million, respectively (a total of $605.6 million), was paid as of January 1, 2004. This adjustment reflects the decrease in interest income due to a reduced cash balance based on an average annual interest rate of 1.5%.	
Supplementary information:
Sensitivity analysis for adjustable rate financing — as part of the refinancing, the new term loan will be subject to adjustable rate of interest. For the year ended December 31, 2004, on a pro forma basis, if the interest rate would increase or decrease by 1/8% for the entire year, income from continuing operations would increase or decrease by $1.8 million, respectively.

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Pro Forma Combined Earnings per Share for the Nine Months Ended September 30, 2005
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	 	Nine Months Ended September 30, 2005 (unaudited)	 	
 	 	 	 	 	 	 	 	 	 	NRG Energy,	 	 	 	 	 	 	 	 	 	 	 	 	 	
(in thousands	 	Historical	 	 	 	 	 	 	Inc, after	 	 	Pro Forma	 	 	Historical	 	 	 	 	 	 	 	
except per share	 	NRG Energy,	 	 	 	 	 	 	Discontinued	 	 	Combined Texas	 	 	West Coast	 	 	Pro Forma Adjustments	 	 	Pro Forma NRG	 	
data)	 	Inc.	 	 	Audrain (2)	 	 	Operations	 	 	Genco LLC (1)	 	 	Power	 	 	ROFR (3)	 	 	Refinancing	 	 	Acquisition	 	 	WCP	 	 	Combined	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	Acquisition (8)	 	 	 	 	 	
Basic EPS:	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Income from continuing operations	 	$	6,991	 	 	$	(336	)	 	$	6,655	 	 	$	343,633	 	 	$	10,765	 	 	$	8,126	 	 	$	14,696	 	 	$	228,995	 	 	$	1,623	 	 	$	614,493	 	
Less:	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Preferred stock dividends	 	 	(13,859	)	 	 	—	 	 	 	(13,859	)	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	(20,625	)(4)	 	 	—	 	 	 	(34,484	)	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Net income/(loss) available to common stockholders from continuing operations	 	$	(6,868	)	 	$	(336	)	 	$	(7,204	)	 	$	343,633	 	 	$	10,765	 	 	$	8,126	 	 	$	14,696	 	 	$	208,370	 	 	$	1,623	 	 	$	580,009	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Weighted average number of common shares outstanding	 	 	85,860	 	 	 	—	 	 	 	85,860	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	58,880	(5)	 	 	—	 	 	 	144,740	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Basic EPS from continuing operations	 	$	(0.08	)	 	 	 	 	 	$	(0.08	)	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	$	4.01	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Diluted EPS:	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Net income/(loss) available to common stockholders from continuing operations	 	$	(6,868	)	 	$	(336	)	 	$	(7,204	)	 	$	343,633	 	 	$	10,765	 	 	$	8,126	 	 	$	14,696	 	 	$	208,370	 	 	$	1,623	 	 	$	580,009	 	
Add:	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Dividend from dilutive Preferred Stock	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	33,225	(6)	 	 	—	 	 	 	33,225	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Net income/(loss) available to common stockholders from continuing operations	 	$	(6,868	)	 	$	(336	)	 	$	(7,204	)	 	$	343,633	 	 	$	10,765	 	 	$	8,126	 	 	$	14,696	 	 	$	241,595	 	 	$	1,623	 	 	$	613,234	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Weighted average number of common shares outstanding	 	 	85,860	 	 	 	—	 	 	 	85,860	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	58,880	(5)	 	 	—	 	 	 	144,740	 	
Incremental shares attributable to the issuance of non-vested restricted stock units (treasury stock method)	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	393	(7)	 	 	—	 	 	 	393	 	
Incremental shares attributable to the assumed conversion of deferred stock units (if-converted method)	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	100	(7)	 	 	—	 	 	 	100	 	
Incremental shares attributable to the issuance of non-vested non-qualifying stock options (treasury stock method)	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	242	(7)	 	 	—	 	 	 	242	 	
Incremental shares attributable to the assumed conversion of the 4% Convertible Perpetual Preferred Stock (if-converted method)	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	10,500	(7)	 	 	—	 	 	 	10,500	 	
Incremental shares attributable to the assumed conversion of the 5.5% Mandatorily Convertible Preferred Stock (if-converted method)	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	10,417	(7)	 	 	—	 	 	 	10,417	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Total dilutive shares	 	 	85,860	 	 	 	—	 	 	 	85,860	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	80,532	 	 	 	—	 	 	 	166,392	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Diluted EPS from continuing operations	 	$	(0.08	)	 	 	 	 	 	$	(0.08	)	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	$	3.69	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
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Footnotes to Pro Forma Combined Earnings per Share for the Nine Months Ended September 30, 2005

(1)	 	The Pro Forma Combined Texas Genco LLC Statement of Operations for the Nine Months Ended September 30, 2005 can be found in Exhibit 99.10.	
 	 	 	
(2)	 	On December 8, 2005 NRG Energy, Inc. signed an Asset and Purchase Sale Agreement with AmerenUE to sell all of the assets of Audrain. For purposes of these pro forma statements we have reflected the sale of assets of Audrain as a discontinued operation.	
 	 	 	
(3)	 	Reflects pro forma results of an additional 13.2% interest in STP acquired in the ROFR for the period from January 1, 2005 until ROFR acquisition date on May 19, 2005.	
 	 	 	
(4)	 	On a pro forma basis it is assumed that 5.5% Mandatorily Convertible Preferred Shares have been issued and outstanding as of January 1, 2004. As such, for the nine months ended September 30, 2005, there is an increase in dividends for preferred dividend of 20,625.	
The 4% Convertible Perpetual Preferred Shares have been issued and outstanding for the entire nine month period ended September 30, 2005 and are already reflected in the historical NRG Earnings per Share calculation.
(5)	 	This increase in the number of weighted average shares is for shares issued to the public, and for the shares issued to the Sellers:	

Shares issued to the Sellers — new issuance	 	 	35,406	 	
Shares issued to the public	 	 	23,474	 	
 	 	 	 	
Total increase in number of weighted average shares	 	 	58,880	 	
 	 	 	 	
It should be noted that for pro forma purposes we have assumed that all the shares issued to the Sellers are newly issued. Per the Acquisition Agreement 19,346,788 shares will be issued from treasury, however, on a pro forma basis that is not possible from January 1, 2004 as there were no shares in treasury. For this reason, the weighted average number of common shares outstanding for the nine months ended September 30, 2005 are also higher than what is expected after the closing of the Acquisition.
(6)	 	This increase in the add back for preferred stock dividends is due to the following dilutive preferred stocks:	

Dividend for 4% Convertible Perpetual Preferred Shares	 	 	12,600	 	
Dividend for 5.5% Mandatorily Convertible Preferred Shares	 	 	20,625	 	
 	 	 	 	
Total Preferred Dividend	 	 	33,225	 	

(7)	 	On a pro-forma basis, these items are dilutive.	

(8)	 	On December 27, 2005, NRG entered into purchase and sale agreements for projects co-owned with Dynegy. Under the agreements, NRG will acquire Dynegy’s 50% ownership interest in WCP, and become the sole owner of WCP’s 1,808 MW of generation in Southern California. In addition, NRG is selling to Dynegy its 50% ownership interest in Rocky Road, a 330 MW gas-fueled, simple cycle peaking plant located in Dundee, Illinois. Both of these transactions are conditioned upon one another and NRG will pay Dynegy a net purchase price of $160 million at closing. NRG will fund the net purchase price with cash held by the WCP partnership. NRG anticipates closing both transactions during the first quarter 2006.	
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Pro Forma Combined Earnings per Share for the Year Ended December 31, 2004
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	 	Year Ended December 31, 2004 (unaudited)	 	 	 	 	
 	 	 	 	 	 	 	 	 	 	NRG Energy,	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	 	Historical	 	 	 	 	 	 	Inc, after	 	 	Pro Forma	 	 	Historical	 	 	Pro Forma Adjustments	 	 	 	 	 	
(in thousands except per	 	NRG Energy,	 	 	 	 	 	 	Discontinued	 	 	Combined Texas	 	 	West Coast	 	 	 	 	 	 	 	 	 	 	 	 	 	 	WCP	 	 	Pro Forma NRG	 	
share data)	 	Inc.	 	 	Audrain (2)	 	 	Operations	 	 	Genco LLC (1)	 	 	Power	 	 	ROFR (3)	 	 	Refinancing	 	 	Acquisition	 	 	Acquisition (7)	 	 	Combined	 	
Basic EPS:	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Income from continuing operations	 	$	159,144	 	 	$	1,628	 	 	$	160,772	 	 	$	306,617	 	 	$	305,947	 	 	$	31,588	 	 	$	38,907	 	 	$	(451,777	)	 	$	(209,292	)	 	$	182,762	 	
Less:	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Preferred stock dividends	 	 	(549	)	 	 	—	 	 	 	(549	)	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	(27,500	)(4)	 	 	—	 	 	 	(28,049	)	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Net income available to common stockholders from continuing operations	 	$	158,595	 	 	$	1,628	 	 	$	160,223	 	 	$	306,617	 	 	$	305,947	 	 	$	31,588	 	 	$	38,907	 	 	$	(479,277	)	 	$	(209,292	)	 	$	154,713	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Weighted average number of common shares Outstanding	 	 	99,616	 	 	 	—	 	 	 	99,616	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	58,880	(5)	 	 	—	 	 	 	158,496	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Basic EPS from continuing operations	 	$	1.59	 	 	 	 	 	 	$	1.61	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	$	0.98	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Diluted EPS:	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Net income available to common stockholders from continuing operations	 	$	158,595	 	 	$	1,628	 	 	$	160,223	 	 	$	306,617	 	 	$	305,947	 	 	$	31,588	 	 	$	38,907	 	 	$	(479,277	)	 	$	(209,292	)	 	$	154,713	 	
Add:	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Dividend from dilutive Preferred Stock	 	 	549	 	 	 	—	 	 	 	549	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	(549	)(6)	 	 	—	 	 	 	—	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Net income available to common stockholders from continuing operations	 	$	159,144	 	 	$	1,628	 	 	$	160,772	 	 	$	306,617	 	 	$	305,947	 	 	$	31,588	 	 	$	38,907	 	 	$	(479,826	)	 	$	(209,292	)	 	$	154,713	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Weighted average number of common shares Outstanding	 	 	99,616	 	 	 	—	 	 	 	99,616	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	58,880	(5)	 	 	—	 	 	 	158,496	 	
Incremental shares attributable to the issuance of non-vested restricted stock units (treasury stock method)	 	 	345	 	 	 	—	 	 	 	345	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	345	 	
Incremental shares attributable to the assumed conversion of deferred stock units (if-converted method)	 	 	67	 	 	 	—	 	 	 	67	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	67	 	
Incremental shares attributable to the assumed conversion of the 4% Convertible Perpetual Preferred Stock (if-converted method)	 	 	343	 	 	 	—	 	 	 	343	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	(343	)(6)	 	 	—	 	 	 	—	 	
Incremental shares attributable to the assumed conversion of the 5.5% Mandatorily Convertible Preferred Stock (if-converted method)	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Total dilutive shares	 	 	100,371	 	 	 	—	 	 	 	100,371	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	—	 	 	 	58,537	 	 	 	—	 	 	 	158,908	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Diluted EPS from continuing operations	 	$	1.59	 	 	 	 	 	 	$	1.60	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	$	0.97	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
24

Table of Contents
Footnotes to Pro Forma Combined Earnings per Share for the Year Ended December 31, 2004

(1)	 	The Pro Forma Combined Texas Genco LLC Statement of Operations for the Year Ended December 31, 2004 can be found in Exhibit 99.11.	
 	 	 	
(2)	 	On December 8, 2005 NRG Energy, Inc. signed an Asset and Purchase Sale Agreement with AmerenUE to sell all of the assets of Audrain. For purposes of these pro forma statements we have reflected the sale of assets of Audrain as a discontinued operation.	
 	 	 	
(3)	 	Amounts reflect the pro forma results of the additional 13.2% interest in STP acquired in the ROFR as if the acquisition had occurred on January 1, 2004.	
 	 	 	
(4)	 	On a pro forma basis it is assumed that the 5.5% Mandatorily Convertible Preferred Shares have been issued and outstanding as of January 1, 2004. As such, for the year ended December 31, 2004, there is an increase in dividends for their respective preferred dividend of 27,500.	
 	 	 	
(5)	 	This increase in the number of weighted average shares is for shares issued to the public, and for the shares issued to the Sellers:	

Shares issued to the Sellers — new issuance	 	 	35,406	 	
Shares issued to the public	 	 	23,474	 	
 	 	 	 	
Total increase in number of weighted average shares	 	 	58,880	 	
 	 	 	 	
It should be noted that for pro forma purposes we have assured that all the shares issued to the Sellers are newly issued. Per the Acquisition Agreement 19,346,788 shares will be issued from treasury, however, on a pro forma basis that is not possible for January 1, 2004 as there were no shares in treasury. For this reason, the weighted average number of common shares outstanding for the nine months ended September 30, 2005 are also higher than what is expected after the closing of the Acquisition.
(6)	 	On a pro-forma basis, these items have become anti-dilutive.	
 	 	 	
(7)	 	On December 27, 2005, NRG entered into purchase and sale agreements for projects co-owned with Dynegy. Under the agreements, NRG will acquire Dynegy’s 50% ownership interest in WCP, and become the sole owner of WCP’s 1,808 MW of generation in Southern California. In addition, NRG is selling to Dynegy its 50% ownership interest in Rocky Road, a 330 MW gas-fueled, simple cycle peaking plant located in Dundee, Illinois. Both of these transactions are conditioned upon one another and NRG will pay Dynegy a net purchase price of $160 million at closing. NRG will fund the net purchase price with cash held by the WCP partnership. NRG anticipates closing both transactions during the first quarter 2006.	
25

Table of Contents
Item 9.01 Exhibits
Exhibits
 	 	 	
23.1*	 	Consent of Deloitte & Touche LLP	
 	 	 	
99.01*	 	Texas Genco LLC Quarterly Report to the Noteholders for the Quarterly Period Ended September 30, 2005	
 	 	 	
99.02*	 	Texas Genco Holdings, Inc. audited financial statements as of December 31, 2003 and December 31, 2004	
 	 	 	
99.03*	 	Texas Genco LLC audited financial statements as of December 31, 2004	
 	 	 	
99.04*	 	Pro Forma presentation of the Statements of Operation for Predecessor NRG Energy, Inc. for the year ended December 31, 2002, for the period January 1 through December 5, 2005 to reflect the reclassification for discontinued operations of Audrain	
 	 	 	
99.05*	 	Pro Forma presentation of the Statement of Operation for Reorganized NRG Energy, Inc.’s for the period December 6, 2003 through December 31, 2003 to reflect the reclassification for discontinued operations of Audrain	
 	 	 	
99.06	 	Unaudited Quarterly Financial Statements for West Coast Power LLC	
 	 	 	
99.10*	 	Combined Texas Genco LLC pro forma financial statements for the nine months ended September 30, 2005	
 	 	 	
99.11*	 	Combined Texas Genco LLC pro forma financial statements for the year ended December 31, 2004	

*   Incorporated herein by reference to NRG Energy, Inc.’s current report on Form 8-K filed on December 21, 2005.	
26

Table of Contents
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.
 	 	 	 	 	
 	NRG Energy, Inc.
(Registrant)
 	 	
 	By:  	/s/ TIMOTHY W. J. O’BRIEN  	 	
 	 	Timothy W. J. O’Brien 	 	
 	 	Vice President and General Counsel 	 	
 	
Dated: January 5, 2005
27

Table of Contents
 	 	 	
Exhibits	 	 	
23.1*	 	Consent of Deloitte & Touche LLP	
 	 	 	
99.01*	 	Texas Genco LLC Quarterly Report to the Noteholders for the Quarterly Period Ended September 30, 2005	
 	 	 	
99.02*	 	Texas Genco Holdings, Inc. audited financial statements as of December 31, 2003 and December 31, 2004	
 	 	 	
99.03*	 	Texas Genco LLC audited financial statements as of December 31, 2004	
 	 	 	
99.04*	 	Pro Forma presentation of the Statements of Operation for Predecessor NRG Energy, Inc. for the year ended December 31, 2002, for the period January 1 through December 5, 2005 to reflect the reclassification for discontinued operations of Audrain	
 	 	 	
99.05*	 	Pro Forma presentation of the Statement of Operation for Reorganized NRG Energy, Inc.’s for the period December 6, 2003 through December 31, 2003 to reflect the reclassification for discontinued operations of Audrain	
 	 	 	
99.06	 	Unaudited Quarterly Financial Statements for West Coast Power LLC	
 	 	 	
99.10*	 	Combined Texas Genco LLC pro forma financial statements for the nine months ended September 30, 2005	
 	 	 	
99.11*	 	Combined Texas Genco LLC pro forma financial statements for the year ended December 31, 2004	

*   Incorporated herein by reference to NRG Energy, Inc.’s current report on Form 8-K filed on December 21, 2005.	
28

 
Exhibit 99.06
WEST COAST POWER LLC
INDEX TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
 	 	 	 	 	
 	 	Page	 	
Condensed Consolidated Financial Statements	 	 	 	 	
Condensed Consolidated Balance Sheets as of September 30, 2005 and December 31, 2004	 	 	2	 	
Condensed Consolidated Statements of Operations for the three and nine months ended September 30, 2005 and 2004	 	 	3	 	
Condensed Consolidated Statements of Cash Flows for the nine months ended September 30, 2005 and 2004	 	 	4	 	
Notes to Condensed Consolidated Financial Statements	 	 	5	 	

 
WEST COAST POWER LLC
CONDENSED CONSOLIDATED BALANCE SHEETS
(unaudited) (in thousands)
 	 	 	 	 	 	 	 	 	
 	 	September 30,	 	 	December 31,	 	
 	 	2005	 	 	2004	 	
ASSETS	 	 	 	 	 	 	 	 	
Current Assets	 	 	 	 	 	 	 	 	
Cash and cash equivalents	 	$	176,612	 	 	$	208,730	 	
Accounts receivable, net of allowance for doubtful accounts of $3,597 and $1,032, respectively	 	 	48,372	 	 	 	113,794	 	
Inventory	 	 	20,462	 	 	 	21,318	 	
Prepaid expenses	 	 	36,340	 	 	 	52,121	 	
Assets from risk-management activities	 	 	88,816	 	 	 	33,231	 	
 	 	 	 	 	 	 	
Total Current Assets	 	 	370,602	 	 	 	429,194	 	
 	 	 	 	 	 	 	
Property, Plant and Equipment	 	 	600,144	 	 	 	596,776	 	
Accumulated depreciation	 	 	(219,224	)	 	 	(203,060	)	
 	 	 	 	 	 	 	
Property, Plant and Equipment, Net	 	 	380,920	 	 	 	393,716	 	
 	 	 	 	 	 	 	
Total Assets	 	$	751,522	 	 	$	822,910	 	

LIABILITIES AND MEMBERS’ EQUITY	 	 	 	 	 	 	 	 	
Current Liabilities	 	 	 	 	 	 	 	 	
Accounts payable	 	$	904	 	 	$	1,694	 	
Accounts payable, affiliates	 	 	16,302	 	 	 	33,529	 	
Accrued liabilities and other current liabilities	 	 	4,894	 	 	 	10,132	 	
Liabilities from risk-management activities	 	 	88,643	 	 	 	36,790	 	
 	 	 	 	 	 	 	
Total Current Liabilities	 	 	110,743	 	 	 	82,145	 	
 	 	 	 	 	 	 	
Asset retirement obligation	 	 	5,472	 	 	 	5,223	 	
 	 	 	 	 	 	 	
Total Liabilities	 	 	116,215	 	 	 	87,368	 	
 	 	 	 	 	 	 	
Total Members’ Equity	 	 	635,307	 	 	 	735,542	 	
 	 	 	 	 	 	 	
Total Liabilities and Members’ Equity	 	$	751,522	 	 	$	822,910	 	
 	 	 	 	 	 	 	
See the notes to the condensed consolidated financial statements.
2

 
WEST COAST POWER LLC
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(unaudited) (in thousands)
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	 	Three Months Ended	 	 	Nine Months Ended	 	
 	 	September 30,	 	 	September 30,	 	
 	 	2005	 	 	2004	 	 	2005	 	 	2004	 	
Revenues	 	$	60,089	 	 	$	182,444	 	 	$	216,127	 	 	$	534,843	 	
Affiliate operating costs, exclusive of depreciation shown separately below	 	 	(39,678	)	 	 	(81,021	)	 	 	(159,048	)	 	 	(228,363	)	
Non-affiliate operating costs, exclusive of depreciation shown separately below	 	 	(8,082	)	 	 	(11,330	)	 	 	(31,413	)	 	 	(33,117	)	
Depreciation and amortization expense	 	 	(5,295	)	 	 	(7,497	)	 	 	(16,726	)	 	 	(22,682	)	
Gain on sale of assets	 	 	—	 	 	 	—	 	 	 	2	 	 	 	689	 	
General and administrative expenses	 	 	(1,161	)	 	 	(852	)	 	 	(2,831	)	 	 	(3,207	)	
 	 	 	 	 	 	 	 	 	 	 	 	 	
Operating income	 	 	5,873	 	 	 	81,744	 	 	 	6,111	 	 	 	248,163	 	
Interest income	 	 	1,624	 	 	 	739	 	 	 	4,654	 	 	 	1,450	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	
Net income	 	$	7,497	 	 	$	82,483	 	 	$	10,765	 	 	$	249,613	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	
Comprehensive income	 	$	7,497	 	 	$	82,483	 	 	$	10,765	 	 	$	249,613	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	
See the notes to the condensed consolidated financial statements.
3

 
WEST COAST POWER LLC
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(unaudited) (in thousands)
 	 	 	 	 	 	 	 	 	
 	 	Nine Months Ended	 	
 	 	September 30,	 	
 	 	2005	 	 	2004	 	
CASH FLOWS FROM OPERATING ACTIVITIES:	 	 	 	 	 	 	 	 	
Net income	 	$	10,765	 	 	$	249,613	 	
Adjustments to reconcile net income to net cash flows from operating activities:	 	 	 	 	 	 	 	 	
Depreciation and amortization	 	 	16,726	 	 	 	22,682	 	
Risk-management activities	 	 	(3,732	)	 	 	1,124	 	
Gain on sale of assets	 	 	(2	)	 	 	(689	)	
Other, non-cash and adjustments	 	 	151	 	 	 	—	 	
Changes in working capital:	 	 	 	 	 	 	 	 	
Accounts receivable, net	 	 	65,422	 	 	 	(34,809	)	
Inventory	 	 	856	 	 	 	839	 	
Prepaid expenses	 	 	15,575	 	 	 	(7,887	)	
Accounts payable	 	 	(18,017	)	 	 	13,345	 	
Accrued liabilities and other current liabilities	 	 	(5,238	)	 	 	8,897	 	
Other	 	 	58	 	 	 	466	 	
 	 	 	 	 	 	 	
Net cash provided by operating activities	 	 	82,564	 	 	 	253,581	 	
 	 	 	 	 	 	 	
CASH FLOWS FROM INVESTING ACTIVITIES:	 	 	 	 	 	 	 	 	
Capital expenditures	 	 	(3,684	)	 	 	(991	)	
Proceeds from asset sales, net	 	 	2	 	 	 	3,278	 	
 	 	 	 	 	 	 	
Net cash provided by (used in) investing activities	 	 	(3,682	)	 	 	2,287	 	
 	 	 	 	 	 	 	
CASH FLOWS FROM FINANCING ACTIVITIES:	 	 	 	 	 	 	 	 	
Distributions	 	 	(111,000	)	 	 	(180,000	)	
 	 	 	 	 	 	 	
Net cash used in financing activities	 	 	(111,000	)	 	 	(180,000	)	
 	 	 	 	 	 	 	
Net increase (decrease) in cash and cash equivalents	 	 	(32,118	)	 	 	75,868	 	
Cash and cash equivalents, beginning of period	 	 	208,730	 	 	 	124,245	 	
 	 	 	 	 	 	 	
Cash and cash equivalents, end of period	 	$	176,612	 	 	$	200,113	 	
 	 	 	 	 	 	 	
See the notes to the condensed consolidated financial statements.
4

 
WEST COAST POWER LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
Note 1—Accounting Policies
     The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with the instructions to interim financial reporting as prescribed by the U.S. Securities and Exchange Commission. The year-end condensed balance sheet data was derived from audited financial statements but does not include all disclosures required by generally accepted accounting principles of the U.S.A. (“GAAP”). These interim financial statements should be read together with the consolidated financial statements and notes thereto included in our consolidated financial statements for the year ended December 31, 2004.
     The unaudited condensed consolidated financial statements contained in this report include all material adjustments that, in the opinion of management, are necessary for a fair statement of the results for the interim periods. These adjustments are of a normal and recurring nature. The results of operations for the interim periods are not necessarily indicative of the results to be expected for the full year or any other interim period, however, due to seasonal fluctuations in demand for our energy products and services, changes in commodity prices, timing of maintenance and other expenditures and other factors. The preparation of the unaudited condensed consolidated financial statements in conformity with GAAP requires management to make estimates and judgments that affect our reported financial position and results of operations. These estimates and judgments also impact the nature and extent of disclosure, if any, of our contingent liabilities. We review significant estimates and judgments affecting our consolidated financial statements on a recurring basis and record the effect of any necessary adjustments prior to the publication of such financial statements. Estimates and judgments are based on information available at the time such estimates and judgments are made. Adjustments made with respect to the use of these estimates and judgments often relate to information not previously available. Uncertainties with respect to such estimates and judgments are inherent in the preparation of financial statements. Estimates and judgments are primarily used in (1) developing fair value assumptions, including estimates of future cash flows and discount rates, (2) analyzing tangible and intangible assets for possible impairment, (3) estimating the useful lives of our assets and (4) determining amounts to accrue for contingencies, guarantees and indemnifications. Actual results could differ materially from any such estimates. Certain reclassifications have been made to prior period amounts in order to conform to current year presentation.
     Inventory. Inventories are valued at the lower of market or cost using the last-in, first-out (“LIFO”) or the average cost methods and are comprised of the following:
 	 	 	 	 	 	 	 	 	
 	 	September 30,	 	 	December 31,	 	
 	 	2005	 	 	2004	 	
 	 	 	 	 	 	(in thousands)	 	
Emissions credits (average cost)	 	$	3,844	 	 	$	4,496	 	
Materials and supplies (average cost)	 	 	3,262	 	 	 	3,446	 	
Fuel oil (LIFO)	 	 	13,356	 	 	 	13,376	 	
 	 	 	 	 	 	 	
 	 	$	20,462	 	 	$	21,318	 	
 	 	 	 	 	 	 	
     Asset Retirement Obligations. At December 31, 2004, our asset retirement obligations (“ARO”) liabilities totaled $5,222,910, which includes monitoring charges related to El Segundo Units 1 and 2 as well as dismantlement and remediation at the Cabrillo II facilities since these assets reside on leased property. We recorded accretion expense during the three and nine months ended September 30, 2005 totaling $116,847 and $505,255, respectively. We recorded accretion expense during the three and nine months ended September 30, 2004 totaling $116,366 and $466,071, respectively. During 2005, the settlement and fair value of the estimated cost to be incurred upon retirement related to the dismantlement and remediation changed for the Cabrillo II facilities. These changes resulted in an $84,659 decrease and a $171,679 decrease, respectively, in our ARO liability during the nine months ended September 30, 2005. At September 30, 2005, our ARO liabilities totaled $5,471,827.
5

 
WEST COAST POWER LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS-(Continued)
(Unaudited)
Note 2—Derivatives and Hedging
     The risk management assets and liabilities as of December 31, 2004 and September 30, 2005 are derivatives, primarily gas and power forward sales contracts and swaps utilized to reduce our exposure from commodity price risk. However, these derivatives are not designated as cash flow hedges as defined in Statement of Financial Accounting Standard (“SFAS”) No. 133, “Accounting for Derivative Instruments and Hedging Activities.” The balance at September 30, 2005 consisted of only instruments that mature in the fourth quarter 2005.
Note 3—Related Parties
     We purchase fuel for our plants under full requirement natural gas supply agreements (“GSAs”) with Dynegy Marketing and Trade (“DMT”), one of our affiliates. We contract with Dynegy Power Marketing Inc. (“DPM”) to provide all power scheduling, power marketing and risk management for us under an energy management agreement (the “EMA”). Dynegy Holdings Inc. (“Dynegy”) also provides administrative services such as business management and accounting (the “ASMA” agreement). We have contracted with NRG, one of our affiliates, to provide operation and maintenance (“O&M”) services and other administrative services (“AMA”) not covered under the O&M agreements
     As described above, our affiliates provide various services for us. Charges for these services are included in our operating and general and administrative expenses in the unaudited condensed consolidated statements of operations and consisted of the following costs:
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	 	Three Months Ended	 	 	Nine Months Ended	 	
 	 	September 30,	 	 	September 30,	 	
 	 	2005	 	 	2004	 	 	2005	 	 	2004	 	
 	 	(in thousands of dollars)	 	
Dynegy related cost:	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Fuel	 	$	29,954	 	 	$	71,079	 	 	$	129,364	 	 	$	193,517	 	
EMA charges	 	 	1,093	 	 	 	2,482	 	 	 	3,277	 	 	 	7,517	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	
Charges included in operating costs	 	$	31,047	 	 	$	73,561	 	 	$	132,641	 	 	$	201,034	 	
ASMA fees included in general and administrative expenses	 	$	370	 	 	$	556	 	 	$	825	 	 	$	1,632	 	
NRG related cost:	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
O&M charges included in operating costs	 	$	8,631	 	 	$	7,460	 	 	$	26,407	 	 	$	27,328	 	
AMA charges included in general and administrative expenses	 	$	479	 	 	$	590	 	 	$	640	 	 	$	1,493	 	
     Distributions to our partners totaled $111 million and $180 million for the nine months ended September 30, 2005 and 2004, respectively.
Note 4—Power Purchase Agreement
     We entered into a long-term Power Purchase Agreement with the California Department of Water Resources (“CDWR”) in March 2001. The CDWR contract expired by its terms on December 31, 2004.
     All units, except the El Segundo units, have been re-designated Reliability Must Run (“RMR”) units for 2006 and will operate under RMR agreements with the California ISO. The RMR contracts for the El Segundo units expire December 31, 2005. However, in the fourth quarter 2005, we have entered into a power sales agreement with a major California utility for the sale of 100% of the capacity and associated energy from the El Segundo facility from May 2006 through April 2008. During the term of this agreement, the utility will be entitled to primary energy
6

 
WEST COAST POWER LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS-(Continued)
(Unaudited)
dispatch right for the facility’s generating capacity. The revenues from this agreement are expected to at least offset revenues that El Segundo could have otherwise received under an RMR agreement.
Note 5—Debt
     During the three and nine-month periods ended September 30, 2005, our deposit for collateral under our credit facility decreased by $19.6 million and $14.6 million, respectively. During the three and nine-month periods ended September 30, 2005, we decreased letters of credit under our $85 million facility by $2.1 million and $17.8 million respectively. At September 30, 2005 and December 31, 2004, our deposit for collateral was $20.7 million and $35.3 million, respectively. Of these amounts, $10.7 million and $28.5 million, respectively, were issued in letters of credit.
Note 6—Commitments and Contingencies
     Set forth below is a description of our material legal proceedings. In addition to the matters described below, we are party to legal proceedings arising in the ordinary course of business. In management’s opinion, the disposition of these matters will not materially adversely affect our financial condition, results of operations, or cash flows.
     We record reserves for estimated losses from contingencies when information available indicates that a loss is probable and the amount of the loss is reasonably estimable under SFAS No. 5, “Accounting for Contingencies”. For environmental matters, we record liabilities when remedial efforts are probable and the costs can be reasonably estimated. Please see Note 2 of our year-end audited financial statements for further discussion. Environmental reserves do not reflect management’s assessment of the insurance coverage that may be applicable to the matters at issue. We cannot guarantee that the amount of any reserves will cover any cash obligations we might incur as a result of litigation or regulatory proceedings, payment of which could be material.
     With respect to some of the items listed below, management has determined that a loss is not probable or that any such loss, to the extent probable, is not reasonably estimable. In some cases, management is not able to predict with any degree of certainty the range of possible loss that could be incurred. Notwithstanding these facts, management has assessed these matters based on current information and made a judgment concerning their potential outcome, giving due consideration to the nature of the claim, the amount and nature of damages sought and the probability of success. Management’s judgment may, as a result of facts arising prior to resolution of these matters or other factors, prove inaccurate and investors should be aware that such judgment is made subject to the known uncertainty of litigation.
     California Market Litigation. We and various other power generators and marketers were defendants in numerous lawsuits alleging rate and market manipulation in California’s wholesale electricity market during the California energy crisis and seeking unspecified treble damages. The cases included:  Pamela R. Gordon v. Reliant Energy Inc., et al.; Ruth Hendricks v. Dynegy Power Marketing, et al.; The People of the State of California v. Dynegy Power Marketing, et al.; Sweetwater Authority v. Dynegy Inc., et al.; People of the State of California ex rel. Bill Lockyer, Attorney General v. Dynegy Inc., et al.; Public Utility District No. 1 of Snohomish County v. Dynegy Power Marketing, et al.; and Bustamante [I] v. Dynegy Inc., et al.  These cases were coordinated before a single federal judge, who dismissed two of them,  Lockyer  and  Snohomish County , in the first quarter of 2003 on the grounds of FERC preemption and the filed rate doctrine. The Ninth Circuit Court of Appeals affirmed these dismissals in June 2004 and September 2004, respectively. In  Lockyer , plaintiffs’ Petition for Writ of Certiorari to the U.S. Supreme Court was denied in April 2005. Plaintiffs in  Snohomish County  filed a Petition for Writ of Certiorari to the U.S. Supreme Court in November 2004 that was denied in June 2005. The remaining five coordinated cases were remanded to a California state court, and in May 2005, defendants filed a motion to dismiss. The court granted defendants’ motion to dismiss in October 2005 on grounds of federal preemption. Plaintiffs have appealed the court’s ruling.
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WEST COAST POWER LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS-(Continued)
(Unaudited)
     Between April and October 2002, the following nine additional putative class actions and/or representative actions were filed in state and federal court on behalf of business and residential electricity consumers against us and numerous other power generators and marketers:  Pier 23 Restaurant v. PG&E Energy Trading, et al.; Bronco Don Holdings v. Duke Energy Trading and Marketing, LLC, et al.; T&E Pastorino Nursery v. Duke Energy Trading and Marketing LLC, et al.; Century Theaters, Inc. v. Allegheny Energy Supply Company, et al.; J&M Karsant Family Ltd. Partnership v. Duke Energy Trading and Marketing, LLC, et al.; Leo’s Day & Night Pharmacy v. Duke Energy Trading and Marketing, LLC, et al.; El Super Burrito v. Allegheny Energy Supply Company, LLC, et al.; RDJ Farms, Inc. v. Allegheny Energy Supply Company, et al.; and Millar v. Allegheny Energy Supply Company, LLC, et al.  The complaints allege unfair, unlawful and deceptive practices in violation of the California Unfair Business Practices Act and seek injunctive relief, restitution and unspecified damages. Although some of the allegations in these lawsuits are similar to those in the seven coordinated cases referenced above, these lawsuits include additional allegations relating to, among other things, the validity of the contracts between these power generators and the CDWR. Following removal of these cases, the federal court dismissed eight of the nine actions and plaintiffs appealed. In February 2005, the Ninth Circuit affirmed the dismissals. The remaining case,  Millar , was remanded to state court, and in May 2005, defendants filed a motion to dismiss. In September 2005, the court granted defendants’ motion to dismiss on grounds of federal preemption. No appeal will be taken from this dismissal and the case is now closed.
     In December 2002, two additional actions were filed on behalf of consumers and businesses in Oregon, Washington, Utah, Nevada, Idaho, New Mexico, Arizona and Montana that purchased energy from the California market, alleging violations of the Cartwright Act and unfair business practices. These cases were subsequently dismissed and refiled in California Superior Court as one class action complaint styled  Jerry Egger v. Dynegy Inc., et al . We removed the action from state court and consolidated it with existing actions pending before the U.S. District Court for the Northern District of California. Plaintiffs challenged the removal and the federal court stayed its ruling pending a decision by the Ninth Circuit on the five coordinated cases referenced above. Although the Ninth Circuit issued a decision remanding those five cases, no ruling has been made with respect to  Egger .
     In May and June 2004, two additional lawsuits, Wah Chang v. Avista Corporation, et al. and City of Tacoma v. American Electric Power Service Corporation, et al.,  were filed in Oregon and Washington federal courts against several energy companies, including DPM, seeking more than $30 million in compensatory damages resulting from alleged manipulation of the California wholesale power markets. In February 2005, the respective federal courts granted our motions to dismiss. Shortly thereafter, plaintiffs in both cases filed notices of appeal to the Ninth Circuit. Both cases remain pending.
     In October 2004, Preferred Energy Services, an independent electric services provider in California, filed suit against us and several other defendants alleging that the defendants, in violation of the California anti-trust and unfair business practices statutes, engaged in unfair, unlawful and deceptive practices in the California wholesale energy market from May 2000 through December 2001. Plaintiff, which formerly sold electricity generated from renewable sources in the California market, claims to have been forced out of business by the defendants’ conduct and is seeking $5 million in compensatory damages, as well as treble damages. We removed the action to federal court in June 2005.
     We believe that we have meritorious defenses to these claims and intend to defend against them vigorously. We cannot predict with certainty whether we will incur any liability or estimate the range of possible loss, if any, that we might incur in connection with these lawsuits. However, given the nature of the claims, an adverse result in any of these proceedings could have a material adverse effect on our financial condition, results of operations and cash flows.
     FERC and Related Regulatory Investigations—Requests for Refunds. In October 2004, the FERC approved in all respects the agreement announced by Dynegy and West Coast Power in April 2004, which provided for the settlement of FERC claims relating to western energy market transactions that occurred from January 2000 through
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WEST COAST POWER LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS-(Continued)
(Unaudited)
June 2001. Market participants (other than the parties to the settlement) were permitted to opt into this settlement and share in the distribution of the settlement proceeds, and most of these other market participants have done so. The California Independent System Operator (“Cal ISO”) will determine the entitlement to refund and/or the liability of each non-settling market participant. Under the terms of the settlement, we will have no further liability to these non-settling parties. The settlement further provides that we are entitled to pursue claims for reimbursement of fuel costs against various non-settling market participants. We are currently pursuing these claims but are unable to predict the amounts that may be recovered from such parties.
     The settlement does not apply to the ongoing civil litigation related to the California energy markets described above in which Dynegy and West Coast Power are defendants. The settlement also does not apply to the pending appeal by the CPUC and the California Electricity Oversight Board of the FERC’s prior decision to affirm the validity of the West Coast Power-CDWR contract. We are currently awaiting a ruling on this appeal and cannot predict their outcome.
     Gas Index Pricing Litigation. We are defending the following suits claiming damages resulting from the alleged manipulation of gas index publications and prices by WCP and/or the LLCs and numerous other power generators and marketers:  ABAG v. Sempra Energy et al.  (filed in state court in November 2004);  Bustamante v. Williams Energy Services et al.  (class action filed in state court in November 2002);  City and County of San Francisco v. Dynegy Inc. et al.  (filed in state court in July 2004);  County of Alameda v. Sempra Energy  (filed in state court in October 2004);  County of San Diego v. Dynegy Inc., Dynegy Marketing and Trade, West Coast Power, et al.  (filed in state court in July 2004);  County of San Mateo v. Sempra Energy et al.  (filed in state court in December 2004);  County of Santa Clara v. Dynegy Inc., Dynegy Marketing and Trade, West Coast Power, et al.  (filed in state court in July 2004);  Fairhaven Power Company v. Encana Corp. et al.  (class action filed in federal court in September 2004);  Ableman Art Glass v. EnCana Corp., et al.  (filed in federal court in December 2004);  Nurserymen’s Exchange v. Sempra Energy et al.  (filed in state court in October 2004);  In re: Natural Gas Commodity Litigation  (filed in federal court in January 2004);  Older v. Dynegy Inc. et al . (filed in federal court in September 2004);  Sacramento Municipal Utility District (SMUD) v. Reliant Energy Services, et al.  (filed in state court in November 2004);  Texas-Ohio Energy, Inc. v. CenterPoint Energy Inc., et al.  (class action filed in federal court in November 2003);  School Project for Utility Rate Reduction v. Sempra Energy, et al.  (filed in state court in November 2004);  Tamco, et al. v. Dynegy, Inc., et al.  (filed in state court in December 2004); Ever-Bloom, Inc. v. AEP Energy Services, Inc., et al. (filed in federal court in November 2004) and  Utility Savings & Refund v. Reliant Energy Services, et al . (class action filed in federal court in November 2004). In each of these suits, the plaintiffs allege that we and other energy companies engaged in an illegal scheme to inflate natural gas prices by providing false information to gas index publications, thereby manipulating the price. All of the complaints rely heavily on the FERC and CFTC investigations into and report concerning index-reporting manipulation in the energy industry. The plaintiffs generally seek unspecified actual and punitive damages relating to costs they claim to have incurred as a result of the alleged conduct.
     Pursuant to various motions filed by the parties to the litigation described above, the gas index pricing lawsuits pending in state court have been consolidated before a single judge in state court in San Diego. These cases are now entitled the “Judicial Counsel Coordinated Proceeding (JCCP) 4221, 4224, 4226, and 4228, the Natural Gas Anti-Trust Cases, I, II, III, & IV”, which we refer to as the “Coordinated Gas Index Cases.” In April 2005, defendants moved to dismiss the Coordinated Gas Index Cases on preemption and filed rate grounds. The Court denied defendants’ motion in June 2005 and in October 2005 the defendants filed answers to the plaintiffs’ complaints. The parties are presently engaged in discovery.
     As to the gas index pricing lawsuits that have been filed in federal court, in Texas-Ohio, the defendants filed a motion to dismiss in May 2004, which the court granted in April 2005. The remaining federal court cases have been transferred to the federal judge in Nevada who presided over the  Texas-Ohio  matter. In the  In re Natural Gas Commodity Litigation  matter, pending in New York federal court, the parties are actively engaged in discovery following denial of the appeal of the previous denial of defendants’ motion to dismiss. In April 2005, defendants
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WEST COAST POWER LLC
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS-(Continued)
(Unaudited)
filed a joint opposition to the motion for class certification filed by the plaintiffs earlier in the year. In October 2005, the Court granted Plaintiffs’ motion and certified the class.
     We are analyzing all of these claims and intend to defend against them vigorously. We cannot predict with certainty whether we will incur any liability or to estimate the damages, if any, that might be incurred in connection with these lawsuits. We do not believe that any liability that we might incur as a result of this litigation would have a material adverse effect on our financial condition, results of operations or cash flows.
     U.S. Attorney Investigations. The United States Attorney’s office in the Northern District of California issued a Grand Jury subpoena requesting information related to our activities in the California energy markets in November 2002. We have been, and intend to continue, cooperating fully with the U.S. Attorney’s office in its investigation of these matters, including production of substantial documents responsive to the subpoena and other requests for information. We cannot predict the ultimate outcome of this investigation.
Note 7—Subsequent Event
     On December 27, 2005, Dynegy entered into an agreement to sell its 50% ownership interest in us to NRG for approximately $205 million, subject to purchase price adjustments. Dynegy and NRG expect the sale to close in the first quarter of 2006.
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