Exhibit 99.2

Thermal Assets

(Unaudited Combined Financial Statements of certain
wholly owned subsidiaries of GDF SUEZ Energy
North America, Inc., See Note 1)

Unaudited Combined Financial Statements as of
March 31, 2016 and December 31, 2015 and for the
Three Months Ended March 31, 2016 and 2015

THERMAL ASSETS

UNAUDITED COMBINED BALANCE SHEETS

AS OF MARCH 31, 2016 AND DECEMBER 31, 2015

(In thousands)

(Continued)

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THERMAL ASSETS

UNAUDITED COMBINED BALANCE SHEETS

AS OF MARCH 31, 2016 AND DECEMBER 31, 2015

(In thousands)

See notes to combined financial statements.

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THERMAL ASSETS

UNAUDITED COMBINED STATEMENTS OF (LOSS) INCOME AND COMPREHENSIVE (LOSS) INCOME

FOR THE THREE MONTHS ENDED MARCH 31, 2016 AND 2015

(In thousands)

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THERMAL ASSETS

UNAUDITED COMBINED STATEMENTS OF PARENT’S EQUITY

FOR THE THREE MONTHS ENDED MARCH 31, 2016 AND 2015

(In thousands)

See notes to combined financial statements.

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THERMAL ASSETS

UNAUDITED COMBINED STATEMENTS OF CASH FLOWS

FOR THE THREE MONTHS ENDED MARCH 31, 2016 AND 2015

(In thousands)

See notes to consolidated financial statements.

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THERMAL ASSETS

NOTES TO COMBINED FINANCIAL STATEMENTS

(UNAUDITED)

AS OF MARCH 31, 2016 AND DECEMBER 31, 2015 AND FOR THE THREE MONTHS ENDED MARCH 31, 2016 AND 2015

Index to Notes to Unaudited Combined Financial Statements

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1.                   DESCRIPTION OF BUSINESS

These unaudited combined financial statements include the following legal entities (ANP Bellingham Energy Company, LLC, ANP Blackstone Energy Company, LLC, ANP ERCOT Acquisition, LLC, ANP Fuel Services, Inc., ANP Funding I, LLC, Armstrong Power, LLC, Calumet Energy Team, LLC, Coleto Creek Power, LP, Coleto LP, LLC, Coleto GP, LLC, Ennis Power Company, LLC, Hays Energy, LLC, Hopewell Cogeneration, LLC, Hopewell Cogeneration Limited Partnership, IPA APT Generation, LLC, IPA Central, LLC, IPA Operations, Inc., Midlothian Energy, LLC, Milford Power, LLC, NEPCO Services Company, Northeastern Power Company, Pleasants Energy, LLC, Prince George Energy Company, LLC, T-Fuels, LLC, Tractebel Associates Northeast LP, Inc., Tractebel Northeast Generation GP, Inc., Troy Energy, LLC, Wharton County Generation, LLC, Wise County Power Company, LLC, Wise-Fuels Pipeline, Inc.) (collectively, “Thermal Assets” or “the Company”) who collectively own certain power-generating facilities as shown in the table below. The Company is engaged in owning and operating retail, industrial, and non-utility wholesale power-generating facilities. The Company is owned by GDF SUEZ Energy North America, Inc. (GSENA or the “Parent”). GSENA is a wholly owned subsidiary of International Power, S.A. (IP), a Belgian company. IP is a wholly owned subsidiary of ENGIE S.A., formerly GDF SUEZ S.A., (ENGIE), a French-domiciled company. As ENGIE owns 100% of IP in the three months ended March 31, 2015 and 2016, it is considered GSENA’s ultimate parent (the “Ultimate Controlling Party”).

Power-generating facilities included in the Thermal Assets are listed below and are 100% owned, with the exception of the Northeast Energy Associates and North Jersey Energy Associates assets, which are 50% owned.

GSENA performs management and administrative activities that support the Thermal Assets and all other GSENA entities. These activities include executive oversight, accounting, treasury, tax, legal, procurement, and information technology. These activities are referred to as “GSENA Corporate”. GSENA will be included in the sale described in Note 13, which is not included in the definition of the business for these combined financial statements.

GSENA owns GDF SUEZ Energy Generation North America (GSEGNA). GSEGNA performs support activities for the Thermal Assets and other generation asset entities.

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GSENA owns GDF SUEZ Energy Marketing North America (GSEMNA). GSEMNA engages in risk management and brokering activities that support the Thermal Assets and all other business units within GSENA. Activities within GSEMNA that support the Thermal Assets are (i) Gas Storage, which is all related to Thermal Assets, (ii) Local Portfolio Management (LPM), which only supports GSEGNA activities, including Thermal Assets, and (iii) all other activities which support the entirety of GSENA, including Thermal Assets.

For the unaudited combined financial statements, GSENA, GSEGNA, and GSEMNA are considered related parties of the Thermal Assets.

2.                   SIGNIFICANT ACCOUNTING POLICIES

Index to Accounting Policies

A. Basis of Presentation and Principles of Combination — The unaudited combined financial statements include the accounts of the Thermal Assets, which are entities under common control and management. All intercompany transactions and accounts between the Thermal Assets have been eliminated. All affiliate transactions between the Thermal Assets and GSENA and its subsidiaries, have been included in these unaudited combined financial statements as related party transactions.

The unaudited combined financial statements include certain assets and liabilities that have historically been held at the GSENA level but are specifically identifiable or otherwise attributable to the Company. The Company prepared its unaudited combined financial statements using the accrual basis of accounting and in accordance with accounting principles generally accepted in the United States of America (U.S. GAAP). The Company’s unaudited combined financial statements have been prepared under the historical cost convention, except for certain derivative financial instruments and share-based compensation measured at fair value. The policies set out below have been consistently applied to all periods presented.

Recent Accounting Pronouncements

Accounting Standards Update (ASU), Revenue from Contracts with Customers (Topic 606). In May 2014, the Financial Accounting Standards Board (FASB) issued revised accounting guidance for revenue recognition from contracts with customers. The core principle of this guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The amendments in this update also require disclosure of sufficient information to allow users to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. For the Company, this guidance is effective for interim and annual periods beginning after December 15, 2018. The Company is currently evaluating the requirements. The ultimate impact of the new standard has not yet been determined.

In July 2015, the FASB issued an update which will require an entity to measure inventory at the lower of cost and net realizable value. Net realizable value is defined as the estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal, and

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transportation. This update is effective on a prospective basis for interim and annual periods beginning after December 15, 2016, with early adoption permitted. Inventory is already valued at the lower of cost or net realizable value, so there will be no impact of this update on the unaudited combined financial statements.

In November 2015, the FASB issued ASU No. 2015-17, Income Taxes (Topic 740). This update requires entities to present deferred tax assets and deferred tax liabilities as noncurrent in the classified balance sheet and eliminates the requirement to allocate a valuation allowance on a pro rata basis between gross current and noncurrent deferred tax assets. The Company early adopted the provisions of this ASU, applied retrospectively as of January 1, 2013.

In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842). This update requires the recognition of lease assets and lease liabilities by lessees for leases classified as operating leases under previous U.S. GAAP. For the Company, this guidance is effective for interim and annual periods beginning after December 15, 2019. The Company is currently evaluating the requirements. The ultimate impact of the new standard has not yet been determined.

B. Use of Estimates—The preparation of unaudited combined financial statements in conformity with U.S. GAAP requires management to make estimates and judgments that affect the reported amount of assets, liabilities, revenues, and expenses, as well as disclosures of contingent assets and liabilities. Significant estimates and judgments affecting the unaudited combined financial statements are reviewed on a recurring basis, and we record the effect of any necessary adjustments. Uncertainties with respect to such estimates and judgments are inherent in the preparation of unaudited combined financial statements. Estimates and judgments are used in, among other things, (i) developing fair value assumptions to determine the fair value of financial instruments, including derivatives, that are not actively listed on a market, (ii) estimating the useful lives of our assets and asset retirement obligations (AROs), (iii) assessing future tax exposure and the realization of deferred tax assets, (iv) determining amounts to accrue for contingencies, which include expenditure timing, the discount rate applied to future cash flows, and the actual level of expenditure, and (v) valuing the pension assets and liabilities using models with actuarial assumptions. Delineated within the notes to the unaudited combined financial statements are areas involving at a higher degree of judgment or complexity, or areas where assumptions and estimates are significant to the unaudited combined financial statements. Actual results could differ from the estimates. Management believes the estimates and assumptions used are reasonable.

B.1 Allocation of Corporate Expenses—The unaudited combined statements of (loss) income and comprehensive (loss) income also includes expense allocations for certain corporate functions performed by GSENA and its subsidiaries which have not been historically allocated to the Thermal Assets, including allocations of general corporate expenses related to executive oversight, accounting, treasury, tax, legal, procurement, and information technology. These expenses were systematically allocated to the Thermal Assets based on the percentage of revenues of the Thermal Assets entities to total GSENA revenues and in certain cases based on headcount. Expenses allocated to the Thermal Assets were $9.3 million and $10.5 million for the three months ended March 31, 2016 and 2015, respectively, and are included in other operating expenses—net in the unaudited combined statements of (loss) income and comprehensive (loss) income. These amounts are included in net contribution from parent in the unaudited combined statements of parent’s equity. Also included in this line are other non-cash adjustments primarily for interest expense, income taxes, and the legal contingency. Intercompany transactions between Thermal and GSENA have been included in these unaudited combined financial statements and are considered to be effectively settled for cash in the unaudited combined financial statements at the time the transaction is recorded. The total net effect of the settlement of these intercompany transactions is reflected in

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the unaudited combined statements of cash flows as a financing activity and in the unaudited combined balance sheets as parent equity. Management believes the assumptions underlying the unaudited combined financial statements, including the assumptions regarding allocating balances are reasonable. Nevertheless, the unaudited combined financial statements may not include all of the actual expenses that would have been incurred had the Thermal Assets been a stand-alone company during the periods presented. Actual costs that would have been incurred if the Thermal Assets had been a stand-alone company would depend on multiple factors, including organizational structure and strategic decisions made in various areas.

3.                   INCOME TAXES

The income tax (benefit) provision for the three months ended March 31, 2016 and 2015 consists of the following (in thousands):

The effective tax rate for the three months ended March 31, 2016 and 2015 was 38.73%, and 38.35%, respectively. State and local income taxes had the most significant impact on the difference between the Federal statutory rate of 35% and our effective tax rate.

Deferred income taxes reflect the net effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. The temporary differences that give rise to the deferred tax liabilities as of March 31, 2016 and December 31, 2015 are largely the result of the tax effect of differences in book and tax carrying values with respect to property, plant and equipment and derivatives. The temporary differences that give rise to the deferred tax assets as of March 31, 2016 and December 31, 2015 are largely the result of net operating loss carryovers.

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4.                   PROPERTY, PLANT, AND EQUIPMENT

Movements in property, plant, and equipment as of March 31, 2016 and December 31, 2015, are as follows (in thousands):

Total interest costs incurred for the three months ended March 31, 2016 and 2015 were $11.0 million and $14.0 million, respectively. There was no interest capitalized on construction-in-progress expenditures for the three months ended March 31, 2016 and 2015, respectively.

Depreciation expense for the three months ended March 31, 2016 and 2015 was $57.0 million and $56.0 million, respectively. In the first quarter of 2016, the Company recorded impairment expense of $6.5 million related to gas turbine parts that are expected to be sold in the second quarter of 2016.

The Company also transferred $0.1 million from prepaid expenses to property, plant, and equipment related to maintenance performed under LTSAs in the three months ended March 31, 2016. $3.5 million was transferred from other payables to property, plant, and equipment in the three months ended March 31, 2016, related to maintenance performed under LTWAs. Thermal Assets accrued an insignificant amount of non-maintenance property, plant, and equipment costs in the three months ended March 31, 2016.

Capital Commitments—In the ordinary course of operations, the Company enters into commitments related to the purchase or construction of property, plant, and equipment. The Company’s projected committed capital expenditures for maintenance performed under LTSAs are $1.1 billion.

5.                   EQUITY METHOD INVESTMENTS

The Company has one investment in a joint venture, Northeast Energy LP (NELP). The Company owns 50% of the equity interest, voting rights, and legal ownership interest of NELP and accounts for its interest using the equity method. NELP wholly owns the Northeast Energy Associates and North Jersey Energy Associates, LP.

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Key Figures of NELP (Unaudited)—As of March 31, 2016 and December 31, 2015 and for the three months ended March 31, 2016 and 2015, the key figures of NELP presented on a 100% basis, are as follows (in thousands):

The Company’s share of the underlying equity of NELP is not equal to its ownership percentage in NELP due to a disproportionate distribution of earnings compared to the underlying equity interests.

6.                   RISK MANAGEMENT ACTIVITIES

6.1 Risk Management Activities—The Company utilizes a variety of financial and physical instruments to mitigate its exposures to market risk created by the Company’s physical generation and financing activities. Those market risks include exposures to interest rates and energy and energy-related commodity prices. Risk management activities are broadly defined by two major categories—financial and commodity.

Financial Risk Management Derivatives—The Company manages its exposure to fluctuations in interest rates using an interest-rate swap. It effectively converts a portion of its floating-rate debt to a fixed-rate basis, thus reducing the impact of interest rate changes on future income. The agreement involves the receipt of floating-rate amounts in exchange for fixed-rate interest payments over the life of the agreement without an exchange of the underlying principal amount. The interest-rate swap is accounted for as a cash flow hedge designated at inception, with changes in fair value captured directly in equity until the hedged transactions occur and are recognized in earnings. The interest-rate swap expired in the second half of 2015.

ENGIE entered into warrant agreements under which it will receive cash to settle its liability incurred via stock appreciation rights issued to employees. The Company has been allocated a portion of the liability and associated warrant agreements based on headcount. The fair value of the warrants for the Company was under $1 million as of March 31, 2016 and December 31, 2015, respectively, which was included in risk management assets on the unaudited combined balance sheets as of such dates. The Company recognized the warrants’ change in value in personnel costs. The counterparty to those warrants is an investment-grade entity, and those warrants will continue to settle throughout 2016.

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Commodity Risk Management Derivatives—The Company manages commodity price risk arising from changes in fuel costs and future electricity prices related to its power-generating facilities.

The Company uses commodity swap and option contracts, forward physicals, and futures to manage its price risk exposure related to natural gas and coal purchases for its power plants. Under the swaps and futures, the Company pays a fixed price and receives a floating price, which effectively fixes the price it will pay for the natural gas.

The Company enters into commodity swap and option contracts and forward physicals to mitigate its exposure to the effect of changes in future electricity prices on its power plants’ sales. Under the swaps, the Company pays a variable price and receives a fixed price, which effectively fixes the price to be received for the electricity.

Other Commodity Contracts—The Company’s physical electricity capacity sales contracts and gas and power contracts qualify for the election of the NPNS scope exception. Under the NPNS exception, the Company’s physical electric capacity contracts fair value is not recognized in the unaudited combined balance sheets.

The Company’s financial and commodity derivative results as of March 31, 2016 and 2015, are as follows (in thousands):

A summary of the Company’s outstanding commodity derivative volumes is shown below as of March 31, 2016 and December 31, 2015. The volumes disclosed represent the notional volumes of commodity contracts excluding NPNS (in thousands):

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Balance Sheet Treatment—The Company accounts for its derivatives at fair value on the unaudited combined balance sheet. A summary of the Company’s derivative current and noncurrent assets and liabilities as of March 31, 2016 and December 31, 2015, is as follows (in thousands):

Commercial contracts marked to market as disclosed in the table above refers to contracts that support the Company’s core business lines, but are required to be marked to market under ASC 815, as they are not scoped out of ASC 815 under the NPNS exception, and they do not qualify as accounting hedges. These contracts include short-term and medium-term purchases of natural gas and coal with volumetric variability. The realized expense from these commercial contracts represent physical settlement of these contracts at contract prices, and is recorded in fuel purchases and other costs of operations with the remainder of the Company’s commercial activity.

Accounting for Cash Flow Hedges—For derivatives not designated as cash flow hedges, the Company immediately recognizes changes in the fair value of nonhedge derivatives in the income on mark-to-market on commodity contracts line of the unaudited combined statements of (loss) income and comprehensive (loss) income.

The Company recognizes the effective portion of changes in fair values of derivatives appropriately documented as cash flow hedges of forecasted transactions in equity until the hedged transactions occur and are recognized in earnings. The ineffective portion of a hedging derivative’s change in fair value is recognized in earnings in the period of change.

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The movements in other comprehensive loss resulting from the Company’s cash flow hedge activity, including the recognition of ineffectiveness in earnings as of March 31, 2016 and 2015, are as follows (in thousands):

Accounting for the Settlement of Risk Management Derivatives—When the Company realizes its mark-to-market assets and liabilities related to its risk management activities, it records that settled result in operating earnings. The Company reflects electricity and steam sales as electricity and thermal sales and records the cost of purchasing fuel commodities to satisfy those sales in fuel purchases and other costs of operations in the unaudited combined statements of (loss) income and comprehensive (loss) income. For the three months ended March 31, 2016 and 2015, the Company recorded the settlement of risk management derivatives as follows (in thousands):

6.2 Market and Liquidity Risk—The commodity and financing activities of GSENA, which includes the Company, are subject to the risk of changes in forward commodity prices. GSENA has established and monitors various controls to manage its risk. A risk committee composed of members of senior management meet at least monthly to analyze any transaction that is not explicitly approved by documented hedging policies.

Market risk arising from commodity derivative instruments utilized in risk management activities is assessed, measured, and managed using sensitivity analysis, together with other market risk exposure indicators.

Because the Company’s risk management activities contractually obligate it to exchange commodities and cash flows based on commodity prices at future dates, the Company is exposed to the risk that it will not be able to purchase or sell commodities at those dates to fulfill its obligations. That liquidity risk can limit the ability to mitigate market price risk exposure. The Company applies a valuation reserve to adjust the fair value of its mark-to-market commodity assets and liabilities to fair value.

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6.3 Major Customers and Concentrations of Credit Risk—Credit risk relates to the risk of loss associated with nonperformance by counterparties. The Company entities transact with GSEMNA and GSEMNA transacts with third party counterparties. GSEMNA is considered a related party with the Company. As such, a significant concentration of credit risk for the Company is with GSEMNA, with a maximum exposure of $83.8 million and $85.9 million as of March 31, 2016 and December 31, 2015, respectively. The exposure does not include NPNS contracts. The Company is exposed to an insignificant amount of credit risk with utility and industrial off takers and other third party counterparties. The Company mitigates the risk of its credit exposure with GSEMNA through the use of standardized master agreements that allow for netting of exposures across commodities and termination upon the occurrence of certain events of default. These agreements allow the Company to settle accounts receivable and payable from GSEMNA on a net basis, thereby reducing a potential credit loss arising from GSEMNA.

GSEMNA is exposed to credit risk with third party counterparties. Credit exposure is monitored daily and the financial condition of counterparties is reviewed periodically. Credit enhancements, such as parental guarantees, letters of credit, and margin deposits, are utilized to limit GSEMNA’s credit exposure. GSEMNA posts broker margin and cash collateral with counterparties.

GSENA establishes credit risk policies, which are carried out by GSEMNA. Credit risk policies govern the management of credit risk and establishes controls to determine and monitor the appropriateness of these limits on an ongoing basis. GSENA’s risk mitigation tools include, but are not limited to, the use of standardized master contracts and agreements that allow for netting of exposures across commodities, and termination upon the occurrence of certain events of default.

Some of the power-generating facilities have one primary utility or industrial customer under a long-term contract. The Company does not believe that these customers represent a significant credit risk. However, changes in economic, regulatory, or other factors could have a significant effect on the Company’s contractual relationships. Successful financial operations of these plants are largely dependent on the continued performance by customers and suppliers of their obligations under the relevant power sales contract and, in particular, on the credit quality of the purchasers. If a substantial portion of the Company’s long-term power sales contracts was modified or terminated, the Company would be adversely affected to the extent that it might be unable to find other customers at the same level of contract profitability.

Furthermore, no significant past due financial asset is impaired. The Company assesses financial assets for impairment once those assets have become past due for greater than 60 days. The impairment assessment takes into account the creditworthiness of the applicable counterparty and circumstances that caused the asset to become past due.

The following tables demonstrates the impacts of offsetting recognized derivative assets and liabilities as permitted when the ability and intent to settle such assets and liabilities on a net basis exists: